Dominion Energy nine-month profit falls to $2.12B

Dominion Energy recorded $1.761 billion in common dividend payments during the nine months ended September 30, 2026.

Rhea-AI Filing Summary

Dominion Energy, Inc. reported third-quarter 2026 operating revenue of $5.617 billion, compared with $4.527 billion in 2025, and net income attributable to Dominion of $1.160 billion, versus $1.006 billion. For the first nine months, operating revenue was $15.116 billion, versus $12.413 billion, while net income attributable to Dominion was $2.121 billion, compared with $2.431 billion.

For the nine months ended September 30, 2026, net cash provided by operating activities was $4.688 billion, compared with $4.374 billion in 2025. Investing activities used $8.749 billion, including $8.576 billion for plant construction and other property additions. Financing activities provided $4.281 billion; cash flows included $6.725 billion from issuance and remarketing of long-term debt and $1.713 billion in long-term debt repayments and repurchases. At September 30, 2026, cash and cash equivalents were $435 million, total assets were $124.784 billion, total liabilities were $90.369 billion, and total long-term debt was $48.939 billion.

4 points · 0 major

PositiveiHow this balance works

How this balance works

Rhea-AI gives every point it takes from this document a weight. Minor counts 1, Moderate 3 and Major 9, so one Major point outweighs several Minor ones. The bar adds up the weights on each side, and when neither side holds more than 65% of the total the balance reads Mixed.

It reads the document as published, with the same rules for every company, and it does not look at what the market expected or at how the stock traded, so a point can be objectively good on a day the stock falls.

Rhea-AI Sentiment measures something else, the tone of the wording.

How the balance worksHow Sentiment works

0 major · 1 point

How the balance works

Positive

• Moderate pointThird-quarter operating revenue was $5.617 billion, versus $4.527 billion in 2025.
• Moderate pointThird-quarter net income attributable to Dominion was $1.160 billion, versus $1.006 billion.
• Moderate pointNine-month operating cash flow was $4.688 billion, versus $4.374 billion.
• Minor pointNine-month operating revenue was $15.116 billion, versus $12.413 billion.

Negative

• Minor pointNine-month net income attributable to Dominion was $2.121 billion, versus $2.431 billion.

Filing Explained

This unaudited quarterly report defines the May 15, 2026 NextEra agreement as a conditional two-step merger: Dominion would survive the first merger, then merge into NextEra-owned LLC Sub, which would survive the second.

Key Figures

Operating revenue: $5.617 billion Net income attributable to Dominion: $1.160 billion Operating revenue: $15.116 billion +4 more

7 metrics

Operating revenue $5.617 billion Three months ended September 30, 2026; $4.527 billion in 2025

Net income attributable to Dominion $1.160 billion Three months ended September 30, 2026; $1.006 billion in 2025

Operating revenue $15.116 billion Nine months ended September 30, 2026; $12.413 billion in 2025

Net income attributable to Dominion $2.121 billion Nine months ended September 30, 2026; $2.431 billion in 2025

Net cash provided by operating activities $4.688 billion Nine months ended September 30, 2026; $4.374 billion in 2025

Total assets $124.784 billion As of September 30, 2026

Total long-term debt $48.939 billion As of September 30, 2026

Key Terms

regulatory assets, securitization bonds, noncontrolling interests, AFUDC

4 terms

regulatory assets financial

"Current Assets; Regulatory assets"

Costs or expenses that a regulated company is allowed by a regulator to recover from customers in future rates, recorded on the balance sheet as assets because the company expects to collect them later. Think of it like an IOU the regulator permits the company to collect from future bills; it matters to investors because it affects reported assets, future cash flow timing, and the risk that some or all of those costs may not be approved for recovery.

securitization bonds financial

"Long-Term Debt; Securitization bonds"

Securitization bonds are debt securities created by bundling many similar loans or receivables (like mortgages, car loans, or credit-card debt) and selling slices of the cash flow to investors. Think of it like cutting a stream of customer payments into smaller, sellable pieces; investors receive regular payments funded by those underlying borrowers. They matter because returns and safety depend on the quality of the original loans and the structure of the deal, so they carry risks tied to defaults, prepayments and any built-in protection layers.

noncontrolling interests financial

"Net income including noncontrolling interests"

The portion of a subsidiary’s equity and profits that belongs to outside owners rather than the parent company; when a parent reports consolidated results it includes the whole subsidiary but shows the noncontrolling slice separately. Think of a company’s subsidiary as a pie where the parent owns most slices but some are held by other investors — noncontrolling interests tell you how much of the pie and its future earnings don’t belong to the parent, which affects how much profit and net assets are truly attributable to the parent’s shareholders.

AFUDC financial

"AFUDC | Allowance for funds used during construction"

Allowance for Funds Used During Construction (AFUDC) is an accounting method that adds the cost of financing — typically interest and sometimes a return — to the value of a long-term project while it’s being built, rather than charging that cost immediately as an expense. Think of it like capitalizing the loan interest on a house while it’s under construction so the cost becomes part of the asset; this raises reported asset value and delays expense recognition, which can make current earnings look stronger and affect future regulated rates and investor returns.

FAQ

AI-generated questions and answers. How Rhea-AI works. Not financial advice.

How much revenue did Dominion Energy (D) report?

Dominion Energy reported third-quarter 2026 operating revenue of $5.617 billion, compared with $4.527 billion in 2025. For the first nine months, operating revenue was $15.116 billion, versus $12.413 billion.

What was Dominion Energy's (D) net income for the first nine months of 2026?

Net income attributable to Dominion was $2.121 billion for the nine months ended September 30, 2026, compared with $2.431 billion in the same 2025 period. Third-quarter net income attributable to Dominion was $1.160 billion, versus $1.006 billion.

AI-generated analysis. How Rhea-AI works. Not financial advice.

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Available on EDGAR 10/30/2026 - 11:38 AM EDT Accepted by SEC EDGAR 10/30/2026 - 11:38 AM EDT Learn about SEC filing dates

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2026

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number		Exact name of registrants as specified in their charters, address of principal executive offices and registrants’ telephone number		I.R.S. Employer Identification Number
001-08489		DOMINION ENERGY, INC.		54-1229715
000-55337		VIRGINIA ELECTRIC AND POWER COMPANY		54-0418825
		600 East Canal Street Richmond, Virginia 23219 Attn: Corporate Secretary (804) 819-2284

State or other jurisdiction of incorporation or organization of the registrants: Virginia

Securities registered pursuant to Section 12(b) of the Act:

Registrant	Trading Symbol	Title of Each Class	Name of Each Exchange on Which Registered
DOMINION ENERGY, INC.	D	Common Stock, no par value	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Dominion Energy, Inc. Yes ☒ No ☐ Virginia Electric and Power Company Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Dominion Energy, Inc. Yes ☒ No ☐ Virginia Electric and Power Company Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “non-accelerated filer,” “smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Dominion Energy, Inc.

Large accelerated filer	☒		Accelerated filer	☐	Emerging growth company	☐
Non-accelerated filer	☐		Smaller reporting company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Virginia Electric and Power Company

Large accelerated filer	☐		Accelerated filer	☐	Emerging growth company	☐
Non-accelerated filer	☒		Smaller reporting company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Dominion Energy, Inc. Yes ☐ No ☒ Virginia Electric and Power Company Yes ☐ No ☒

At October 23, 2026, the latest practicable date for determination, Dominion Energy, Inc. had 879,566,078 shares of common stock outstanding and Virginia Electric and Power Company had 379,927 shares of common stock outstanding. Dominion Energy, Inc. is the sole holder of Virginia Electric and Power Company’s common stock.

This combined Form 10-Q represents separate filings by Dominion Energy, Inc. and Virginia Electric and Power Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Virginia Electric and Power Company makes no representation as to the information relating to Dominion Energy, Inc.’s other operations.

VIRGINIA ELECTRIC AND POWER COMPANY MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION H(1)(a) AND (b) OF FORM 10-Q AND IS FILING THIS FORM 10-Q UNDER THE REDUCED DISCLOSURE FORMAT.

1

COMBINED INDEX

		Page Number
	Glossary of Terms	3
	PART I. Financial Information
Item 1.	Financial Statements	7
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	63
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	77
Item 4.	Controls and Procedures	78
	PART II. Other Information
Item 1.	Legal Proceedings	79
Item 1A.	Risk Factors	79
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	79
Item 5.	Other Information	79
Item 6.	Exhibits	80

2

GLOSSARY OF TERMS

The following abbreviations or acronyms used in this Form 10-Q are defined below:

Abbreviation or Acronym		Definition
2017 Tax Reform Act		An Act to Provide for Reconciliation Pursuant to Titles II and V of the Concurrent Resolution on the Budget for Fiscal Year 2018 (previously known as The Tax Cuts and Jobs Act) enacted on December 22, 2017
2025 Biennial Review		Virginia Commission review of Virginia Power’s earned return on base rate generation and distribution services for the two successive 12-month test periods beginning January 1, 2023 and ending December 31, 2024 and prospective rate base setting for the succeeding annual periods beginning January 1, 2026 and ending December 31, 2027
2026 Series A JSNs		Dominion Energy’s 2026 Series A Junior Subordinated Notes due 2056
2026 Series B JSNs		Dominion Energy’s 2026 Series B Junior Subordinated Notes due 2056
2027 Biennial Review		Future Virginia Commission review of Virginia Power’s earned return on base rate generation and distribution services for the two successive 12-month test periods beginning January 1, 2025 and ending December 31, 2026 and prospective rate base setting for the succeeding annual periods beginning January 1, 2028 and ending December 31, 2029
AEP		The legal entity American Electric Power Company, Inc., one or more of its consolidated subsidiaries, or the entirety of American Electric Power Company, Inc. and its consolidated subsidiaries
AFUDC		Allowance for funds used during construction
Altavista		Altavista biomass power station
AOCI		Accumulated other comprehensive income (loss)
ARO		Asset retirement obligation
Atlantic Coast Pipeline		Atlantic Coast Pipeline, LLC, a limited liability company owned by Dominion Energy and Duke Energy
Atlantic Coast Pipeline Project		A previously proposed approximately 600-mile natural gas pipeline running from West Virginia through Virginia to North Carolina which would have been owned by Dominion Energy and Duke Energy
bcf		Billion cubic feet
Bedford		A 70 MW solar generation facility in Chesapeake, Virginia
BOEM		Bureau of Ocean Energy Management
Brunswick County		A 1,376 MW combined-cycle, natural gas-fired power station in Brunswick County, Virginia
CAA		Clean Air Act
Canadys Station		A proposed 2.2 GW advanced class combined cycle natural gas-fired power station in Colleton County, South Carolina, to be jointly owned by DESC and Santee Cooper
CCR		Coal combustion residual
CEO		Chief Executive Officer
CERCLA		Comprehensive Environmental Response, Compensation and Liability Act of 1980, also known as Superfund
CFO		Chief Financial Officer
Chesterfield Energy Reliability Center		A proposed 944 MW simple-cycle, natural gas-fired power station in Chesterfield County, Virginia
CO2		Carbon dioxide
CODM		Chief Operating Decision Maker
Community Energy Act		House Bill 2346, known as the Community Energy Act, which was signed into law in the Commonwealth of Virginia in May 2025
Companies		Dominion Energy and Virginia Power, collectively
Contracted Energy		Contracted Energy operating segment
Cooling degree days		Units measuring the extent to which the average daily temperature is greater than 65 degrees Fahrenheit, or 75 degrees Fahrenheit in DESC’s service territory, calculated as the difference between 65 or 75 degrees, as applicable, and the average temperature for that day
Cove Point		Cove Point LNG, LP (formerly known as Dominion Energy Cove Point LNG, LP)
CPCN		Certificate of Public Convenience and Necessity
CVOW Commercial Project		A proposed 2.6 GW wind generation facility 27 miles off the coast of Virginia Beach, Virginia in federal waters adjacent to the CVOW Pilot Project and associated interconnection facilities in and around Virginia Beach, Virginia

3

CVOW Pilot Project		A 12 MW wind generation facility 27 miles off the coast of Virginia Beach, Virginia in federal waters
CWA		Clean Water Act
DES		Dominion Energy Services, Inc.
DESC		The legal entity, Dominion Energy South Carolina, Inc., one or more of its consolidated entities or operating segment, or the entirety of Dominion Energy South Carolina, Inc. and its consolidated entities
DGI		Dominion Generation, Inc.
Dominion Energy		The legal entity, Dominion Energy, Inc., one or more of its consolidated subsidiaries (other than Virginia Power) or operating segments, or the entirety of Dominion Energy, Inc. and its consolidated subsidiaries
Dominion Energy Direct®		A dividend reinvestment and open enrollment direct stock purchase plan
Dominion Energy South Carolina		Dominion Energy South Carolina operating segment
Dominion Energy Virginia		Dominion Energy Virginia operating segment
Dominion Privatization		The legal entity Dominion Utility Privatization Holdings, LLC (a joint venture between Dominion Energy and Patriot), one or more of its consolidated subsidiaries, or the entirety of Dominion Utility Privatization Holdings, LLC and its consolidated subsidiaries
DSM		Demand-side management
DSM Riders		Rate adjustment clauses, designated Riders C1A, C2A, C3A and C4A, associated with the recovery of costs related to certain Virginia DSM programs in approved DSM cases
Dth		Dekatherm
Duke Energy		The legal entity, Duke Energy Corporation, one or more of its consolidated subsidiaries, or the entirety of Duke Energy Corporation and its consolidated subsidiaries
Enel		The legal entity Enel S.p.A, one or more of its consolidated subsidiaries (including Enel Green Power S.p.A), or the entirety of Enel S.p.A and its consolidated subsidiaries
EPA		U.S. Environmental Protection Agency
EPS		Earnings per common share
FERC		Federal Energy Regulatory Commission
FirstEnergy		The legal entity FirstEnergy Corp., one or more of its consolidated subsidiaries, or the entirety of FirstEnergy Corp. and its consolidated subsidiaries
First NextEra Energy Merger		The transaction whereby Merger Sub Corp will merge with and into Dominion Energy with Dominion Energy continuing as the surviving entity pursuant to the terms and subject to the conditions in the NextEra Energy Merger Agreement and the related plan of merger
FTRs		Financial transmission rights
GAAP		U.S. generally accepted accounting principles
GHG		Greenhouse gas
Greensville County		A 1,605 MW combined-cycle, natural gas-fired power station in Greensville County, Virginia
GTSA		Virginia Grid Transformation and Security Act of 2018
GW		Gigawatt
Heating degree days		Units measuring the extent to which the average daily temperature is less than 65 degrees Fahrenheit, or 60 degrees Fahrenheit in DESC’s service territory, calculated as the difference between 65 or 60 degrees, as applicable, and the average temperature for that day
Hopewell		Polyester biomass power station
HSR		Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended
IRA		An Act to Provide for Reconciliation Pursuant to Title II of Senate Concurrent Resolution 14 of the 117th Congress (also known as the Inflation Reduction Act of 2022) enacted on August 16, 2022
ISO		Independent system operator
Jones Act		The Coastwise Merchandise Statute (commonly known as the Jones Act) 46 U.S.C. §55102 regulating U.S. maritime commerce
kV		Kilovolt
kVA		Kilovolt-ampere
LLC Sub		CS Holdco, LLC, a wholly-owned subsidiary of NextEra Energy
LNG		Liquefied natural gas
MD&A		Management’s Discussion and Analysis of Financial Condition and Results of Operations
Merger Sub Corp		WG Development Corp., a wholly-owned subsidiary of NextEra Energy
MGD		Million gallons per day
Millstone		Millstone nuclear power station

4

MMBtu		Metric Million British thermal unit
Moody’s		Moody’s Investors Service
MW		Megawatt
MWh		Megawatt hour
Natural Gas Rate Stabilization Act		Legislation effective February 2005 designed to improve and maintain natural gas service infrastructure to meet the needs of customers in South Carolina
NAV		Net asset value
NextEra Energy		NextEra Energy, Inc., one or more of its consolidated subsidiaries (including Merger Sub Corp and LLC Sub) or operating segments, or the entirety of NextEra Energy, Inc. and its consolidated subsidiaries
NextEra Energy Merger		The First NextEra Energy Merger or First NextEra Energy Merger together with the Second NextEra Energy Merger, as applicable
NextEra Energy Merger Agreement		Agreement and Plan of Merger, dated as of May 15, 2026, by and among NextEra Energy and Dominion Energy
NND Project		V.C. Summer Units 2 and 3 nuclear development project under which DESC and Santee Cooper undertook to construct two Westinghouse AP1000 Advanced Passive Safety nuclear units in Jenkinsville, South Carolina
North Anna		North Anna nuclear power station
North Carolina Commission		North Carolina Utilities Commission
NOX		Nitrogen oxide
NRC		U.S. Nuclear Regulatory Commission
NYSE		New York Stock Exchange
Order 1000		Order issued by FERC adopting requirements for electric transmission planning, cost allocation and development
OSWP		OSW Project LLC, a limited liability company owned by Virginia Power and Stonepeak
ozone season		The period May 1 through September 30, as determined on a federal level
Patriot		Patriot Utility Privatizations, LLC, a joint venture between Foundation Infrastructure Partners, LLC and John Hancock Life Insurance Company (U.S.A.) and affiliates
PJM		PJM Interconnection, LLC
PSD		Prevention of significant deterioration
Pumpkinseed		A 60 MW solar generation facility in Emporia, Virginia
RGGI		Regional Greenhouse Gas Initiative
Rider CCR		A rate adjustment clause associated with the recovery of costs related to the removal of CCR at certain power stations
Rider CE		A rate adjustment clause associated with the recovery of costs related to certain renewable generation, energy storage and related transmission facilities in Virginia, certain small-scale distributed generation projects and related transmission facilities and, beginning May 2024, power purchase agreements for the energy, capacity, ancillary services and renewable energy credits owned by third parties
Rider CERC		A rate adjustment clause associated with the recovery of costs related to the Chesterfield Energy Reliability Center
Rider DIST		A rate adjustment clause associated with the recovery of costs related to electric distribution grid transformation projects that the Virginia Commission has approved as authorized by the GTSA, costs of new underground distribution facilities and, effective June 2026, rural broadband capacity projects
Rider GEN		A rate adjustment clause associated with the recovery of costs related to Altavista, Hopewell, Southampton, Brunswick County, Greensville County, certain solar facilities and the Virginia LNG Storage Facility
Rider OSW		A rate adjustment clause associated with costs incurred to construct, own and operate the CVOW Commercial Project
Rider RGGI		A rate adjustment clause associated with the recovery of costs related to the purchase of allowances through the RGGI market-based trading program for CO2
Rider RPS		A rate adjustment clause associated with the recovery of costs related to the mandatory renewable portfolio standard program established by the VCEA
Rider SNA		A rate adjustment clause associated with costs relating to the preparation of the applications for subsequent license renewal to the NRC to extend the operating licenses of Surry and North Anna and related projects

5

Rider T1		A rate adjustment clause to recover the difference between revenues produced from transmission rates included in base rates, and the new total revenue requirement developed annually for the rate years effective September 1
ROE		Return on equity
RTO		Regional transmission organization
Santee Cooper		South Carolina Public Service Authority
SCANA		The legal entity, SCANA Corporation, one or more of its consolidated subsidiaries, or the entirety of SCANA Corporation and its consolidated subsidiaries
SCANA Combination		Dominion Energy’s acquisition of SCANA completed on January 1, 2019 pursuant to the terms of the agreement and plan of merger entered on January 2, 2018 between Dominion Energy and SCANA
SCANA Merger Approval Order		Final order issued by the South Carolina Commission on December 21, 2018 setting forth its approval of the SCANA Combination
SEC		U.S. Securities and Exchange Commission
Second NextEra Energy Merger		The transaction whereby Dominion Energy will, immediately following the First NextEra Energy Merger, merge with and into LLC Sub with LLC Sub continuing as the surviving entity pursuant to the terms and subject to the conditions in the NextEra Energy Merger Agreement and the related plan of merger
Section 232		Section 232 of the Trade Expansion Act of 1962
Series C Preferred Stock		Dominion Energy’s 4.35% Series C Fixed-Rate Cumulative Redeemable Perpetual Preferred Stock, without par value, with a liquidation preference of $1,000 per share
South Carolina Commission		Public Service Commission of South Carolina
Southampton		Southampton biomass power station
Standard & Poor’s		Standard & Poor’s Ratings Services, a division of S&P Global Inc.
Stonepeak		The legal entity Stonepeak Partners, LLC, one or more of its affiliated investment vehicles (including Dunedin Member LLC) or the entirety of Stonepeak Partners, LLC and its affiliated investment vehicles
Summer		V.C. Summer nuclear power station
Surry		Surry nuclear power station
Valley Link		Valley Link Transmission Company, LLC, a limited liability company owned by Dominion Energy, AEP and FirstEnergy, one or more of its consolidated subsidiaries or the entirety of Valley Link Transmission Company, LLC and its consolidated subsidiaries
VCEA		Virginia Clean Economy Act of March 2020
VEBA		Voluntary Employees’ Beneficiary Association
VIE		Variable interest entity
Virginia Commission		Virginia State Corporation Commission
Virginia LNG Storage Facility		A proposed LNG storage facility in Brunswick and Greensville Counties, Virginia
Virginia Power		The legal entity, Virginia Electric and Power Company, one or more of its consolidated subsidiaries or operating segment, or the entirety of Virginia Electric and Power Company and its consolidated subsidiaries
VPFS		Virginia Power Fuel Securitization, LLC
VPP		Virtual power plant

6

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
(millions, except per share amounts)
Operating Revenue	$	5,617		$	4,527		$	15,116		$	12,413
Operating Expenses
Electric fuel and other energy-related purchases		1,603			1,337			4,524			3,245
Purchased electric capacity		106			36			255			63
Purchased gas		40			31			236			221
Other operations and maintenance		1,070			850			3,039			2,631
Depreciation and amortization		722			609			1,968			1,771
Other taxes		215			195			653			598
Impairment of assets and other charges (benefits)		19			130			878			226
Total operating expenses		3,775			3,188			11,553			8,755
Income from operations		1,842			1,339			3,563			3,658
Other income (expense)		271			432			952			884
Interest and related charges		623			527			1,739			1,513
Income from continuing operations including noncontrolling interests before income     tax expense		1,490			1,244			2,776			3,029
Income tax expense		215			216			385			476
Net Income From Continuing Operations Including Noncontrolling Interests		1,275			1,028			2,391			2,553
Net Income (Loss) From Discontinued Operations Including Noncontrolling     Interests(1)		(1	)		—			(3	)		—
Net Income Including Noncontrolling Interests		1,274			1,028			2,388			2,553
Noncontrolling Interests		114			22			267			122
Net Income Attributable to Dominion Energy	$	1,160		$	1,006		$	2,121		$	2,431
Amounts Attributable to Dominion Energy
Net income from continuing operations	$	1,161		$	1,006		$	2,124		$	2,431
Net income (loss) from discontinued operations		(1	)		—			(3	)		—
Net income attributable to Dominion Energy	$	1,160		$	1,006		$	2,121		$	2,431
EPS - Basic
Net income from continuing operations	$	1.31		$	1.17		$	2.37		$	2.81
Net income (loss) from discontinued operations		—			—			—			—
Net income attributable to Dominion Energy	$	1.31		$	1.17		$	2.37		$	2.81
EPS - Diluted
Net income from continuing operations	$	1.30		$	1.16		$	2.37		$	2.81
Net income (loss) from discontinued operations		—			—			—			—
Net income attributable to Dominion Energy	$	1.30		$	1.16		$	2.37		$	2.81

(1)Includes income tax expense (benefit) of $(1) million and $(2) million for the three months ended September 30, 2026 and 2025, respectively, and $(1) million and $(5) million for the nine months ended September 30, 2026 and 2025 respectively.

The accompanying notes are an integral part of Dominion Energy’s Consolidated Financial Statements.

7

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2026			2025			2026			2025
(millions)
Net income including noncontrolling interests	$	1,274		$	1,028		$	2,388		$	2,553
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities(1)		56			(3	)		65			(19	)
Changes in unrealized net gains (losses) on investment securities(2)		(3	)		6			(4	)		15
Changes in net unrecognized pension and other postretirement benefit     costs (credits)(3)		—			—			—			—
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities(4)		6			7			19			22
Net realized (gains) losses on investment securities(5)		1			(1	)		1			3
Net pension and other postretirement benefit costs (credits)(6)		(2	)		(3	)		(5	)		(8	)
Total other comprehensive income (loss)		58			6			76			13
Comprehensive income including noncontrolling interests		1,332			1,034			2,464			2,566
Comprehensive income (loss) attributable to noncontrolling interests		114			22			267			122
Comprehensive income attributable to Dominion Energy	$	1,218		$	1,012		$	2,197		$	2,444

(1) Net of $(19) million and $2 million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $(22) million and $7 million tax for the nine months ended September 30, 2026 and 2025, respectively.

(2) Net of $2 million and $(5) million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $2 million and $(13) million tax for the nine months ended September 30, 2026 and 2025, respectively.

(3) Net of $— million and $— million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $— million and $— million tax for the nine months ended September 30, 2026 and 2025, respectively.

(4) Net of $(2) million and $(3) million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $(6) million and $(8) million tax for the nine months ended September 30, 2026 and 2025, respectively.

(5) Net of $(1) million and $— million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $(1) million and $(1) million tax for the nine months ended September 30, 2026 and 2025, respectively.

(6) Net of $1 million and $— million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $3 million and $1 million tax for the nine months ended September 30, 2026 and 2025, respectively.

The accompanying notes are an integral part of Dominion Energy’s Consolidated Financial Statements.

8

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

		September 30, 2026				December 31, 2025(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents(2)		$	435			$	250
Customer receivables (less allowance for doubtful accounts of $35 and $31)			3,094				2,531
Tax receivables			479				434
Other receivables (less allowance for doubtful accounts of $3 at both dates)(2)(3)			275				446
Inventories			2,030				1,957
Regulatory assets(2)			2,035				1,380
Derivative assets			221				335
Prepayments(2)			351				377
Other(2)			566				361
Assets held for sale			264				—
Total current assets			9,750				8,071
Investments
Nuclear decommissioning trust funds			10,093				9,166
Investment in equity method affiliates			123				132
Other(2)			397				378
Total investments			10,613				9,676
Property, Plant and Equipment
Property, plant and equipment(2)			112,427				106,315
Accumulated depreciation and amortization(2)			(28,692	)			(27,348	)
Total property, plant and equipment, net			83,735				78,967
Deferred Charges and Other Assets
Goodwill			4,143				4,143
Regulatory assets(2)			8,531				8,276
Other(2)			8,012				6,724
Total deferred charges and other assets			20,686				19,143
Total assets		$	124,784			$	115,857

(1) Dominion Energy’s Consolidated Balance Sheet at December 31, 2025 has been derived from the audited Consolidated Balance Sheet at that date.

(2) See Note 14 for amounts attributable to VIEs.

(3) See Note 9 for amounts attributable to related parties.

The accompanying notes are an integral part of Dominion Energy’s Consolidated Financial Statements.

9

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

		September 30, 2026				December 31, 2025(1)
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year(2)		$	2,399			$	2,409
Supplemental credit facility borrowings			—			—
Short-term debt			3,308				2,457
Accounts payable(2)			1,266				1,338
Accrued interest, payroll and taxes(2)			1,347				1,244
Regulatory liabilities			469				542
Other(2)(3)			2,215				2,454
Liabilities held for sale			132				—
Total current liabilities			11,136				10,444
Long-Term Debt
Long-term debt			40,267				36,778
Securitization bonds(2)			794				883
Junior subordinated notes			7,461				5,978
Supplemental credit facility borrowings			—				—
Other			417				436
Total long-term debt			48,939				44,075
Deferred Credits and Other Liabilities
Deferred income taxes			8,469				7,885
Deferred investment tax credits			1,471				1,591
Regulatory liabilities			9,977				9,072
Other			10,377				9,373
Total deferred credits and other liabilities			30,294				27,921
Total liabilities			90,369				82,440
Commitments and Contingencies (see Note 16)
Equity
Preferred stock (see Note 15)			991				991
Common stock – no par(4)			25,959				25,892
Retained earnings			2,646				2,318
Accumulated other comprehensive loss			(42	)			(118	)
Shareholders’ equity			29,554				29,083
Noncontrolling interests			4,861				4,334
Total equity			34,415				33,417
Total liabilities and equity		$	124,784			$	115,857

(1) Dominion Energy’s Consolidated Balance Sheet at December 31, 2025 has been derived from the audited Consolidated Balance Sheet at that date.

(2) See Note 14 for amounts attributable to VIEs.

(3) See Note 9 for amounts attributable to related parties.

(4) 1.8 billion shares authorized; 880 million shares and 879 million shares outstanding at September 30, 2026 and December 31, 2025, respectively.

The accompanying notes are an integral part of Dominion Energy’s Consolidated Financial Statements.

10

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

QUARTER-TO-DATE

	Preferred Stock						Common Stock
	Shares			Amount			Shares			Amount			Retained Earnings			AOCI			Shareholders’ Equity			Noncontrolling Interests			Total Equity
(millions, except per share amounts)
June 30, 2025		1		$	991			853		$	24,463		$	1,906		$	(145	)	$	27,215		$	3,657		$	30,872
Net income including noncontrolling interests														1,006						1,006			22			1,028
Issuance of stock								1			35									35						35
Stock awards (net of change in unearned    compensation)								—			9									9						9
Contributions from Stonepeak to OSWP																							417			417
Distributions from OSWP to Stonepeak																							(61	)		(61	)
Preferred stock dividends (see Note 15)														(11	)					(11	)					(11	)
Common stock dividends ($0.6675    per common share) and distributions														(570	)					(570	)		—			(570	)
Other comprehensive income (loss), net of tax																	6			6						6
Other											(1	)		2						1			—			1
September 30, 2025		1		$	991			854		$	24,506		$	2,333		$	(139	)	$	27,691		$	4,035		$	31,726
June 30, 2026		1		$	991			880		$	25,947		$	2,084		$	(100	)	$	28,922		$	4,689		$	33,611
Net income including noncontrolling interests														1,160						1,160			114			1,274
Issuance of stock								—			2									2						2
Stock awards (net of change in unearned    compensation)								—			10									10						10
Contributions from Stonepeak to OSWP																							136			136
Distributions from OSWP to Stonepeak																							(78	)		(78	)
Preferred stock dividends (see Note 15)														(11	)					(11	)					(11	)
Common stock dividends ($0.6675    per common share) and distributions														(587	)					(587	)					(587	)
Other comprehensive income (loss), net of tax																	58			58						58
September 30, 2026		1		$	991			880		$	25,959		$	2,646		$	(42	)	$	29,554		$	4,861		$	34,415

11

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

YEAR-TO-DATE

	Preferred Stock						Common Stock
	Shares			Amount			Shares			Amount			Retained Earnings			AOCI			Shareholders’ Equity			Noncontrolling Interests			Total Equity
(millions, except per share amounts)
December 31, 2024		1		$	991			852		$	24,383		$	1,641		$	(152	)	$	26,863		$	2,939		$	29,802
Net income including noncontrolling    interests														2,431						2,431			122			2,553
Issuance of stock								2			105									105						105
Stock awards (net of change in    unearned compensation)								—			25									25						25
Sale of noncontrolling interest in OSWP											(7	)								(7	)					(7	)
Contributions from Stonepeak to OSWP																							1,141			1,141
Distributions from OSWP to Stonepeak																							(167	)		(167	)
Preferred stock dividends (see    Note 15)														(33	)					(33	)					(33	)
Common stock dividends ($2.0025    per common share) and    distributions														(1,708	)					(1,708	)		—			(1,708	)
Other comprehensive income (loss), net of    tax																	13			13						13
Other														2						2			—			2
September 30, 2025		1		$	991			854		$	24,506		$	2,333		$	(139	)	$	27,691		$	4,035		$	31,726
December 31, 2025		1		$	991			879		$	25,892		$	2,318		$	(118	)	$	29,083		$	4,334		$	33,417
Net income including noncontrolling    interests														2,121						2,121			267			2,388
Issuance of stock								1			40									40						40
Stock awards (net of change in    unearned compensation)								—			27									27						27
Contributions from Stonepeak to OSWP																							506			506
Distributions from OSWP to Stonepeak																							(246	)		(246	)
Preferred stock dividends (see    Note 15)														(33	)					(33	)					(33	)
Common stock dividends ($2.0025    per common share) and    distributions														(1,761	)					(1,761	)					(1,761	)
Other comprehensive income (loss), net of    tax																	76			76						76
Other														1						1						1
September 30, 2026		1		$	991			880		$	25,959		$	2,646		$	(42	)	$	29,554		$	4,861		$	34,415

The accompanying notes are an integral part of Dominion Energy’s Consolidated Financial Statements.

12

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Nine Months Ended September 30,		2026				2025
(millions)
Operating Activities
Net income including noncontrolling interests		$	2,388			$	2,553
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)			2,197				2,002
Deferred income taxes			367				455
Deferred investment tax credits (benefits)			(43	)			281
Impairment of assets and other charges (benefits)			873				225
Net (gains) losses on nuclear decommissioning trust funds and other investments			(453	)			(442	)
Other adjustments			(60	)			(35	)
Changes in:
Accounts receivable			(372	)			(63	)
Inventories			(68	)			(124	)
Deferred fuel and purchased gas costs, net			(505	)			(493	)
Prepayments and deposits, net			(174	)			(545	)
Accounts payable			(7	)			(42	)
Accrued interest, payroll and taxes			104				188
Net realized and unrealized changes related to derivative activities			460				551
Pension and other postretirement benefits			(174	)			(205	)
Other operating assets and liabilities			155				68
Net cash provided by operating activities			4,688				4,374
Investing Activities
Plant construction and other property additions (including nuclear fuel)			(8,576	)			(9,255	)
Acquisition of solar development projects			(17	)			(12	)
Proceeds from sales of securities			2,839				2,563
Purchases of securities			(2,935	)			(2,670	)
Contributions to equity method affiliates			(4	)			(20	)
Other			(56	)			(107	)
Net cash used in investing activities			(8,749	)			(9,501	)
Financing Activities
Issuance (repayment) of short-term debt, net			851				22
364-day term loan facility borrowings			1,250				—
Repayment of 364-day term loan facility borrowings			(1,250	)			—
Issuance and remarketing of long-term debt			6,725				7,647
Repayment and repurchases of long-term debt			(1,713	)			(972	)
Repayment of securitization bonds			(85	)			(80	)
Supplemental credit facility borrowings			1,000				—
Supplemental credit facility repayments			(1,000	)			—
Proceeds from sale of noncontrolling interest in OSWP			—				(88	)
Contributions from Stonepeak to OSWP			506				1,141
Distributions from OSWP to Stonepeak			(246	)			(167	)
Issuance of common stock			40				105
Common dividend payments			(1,761	)			(1,708	)
Other			(36	)			(72	)
Net cash provided by financing activities			4,281				5,828
Increase (decrease) in cash, restricted cash and equivalents			220				701
Cash, restricted cash and equivalents at beginning of period			343				365
Cash, restricted cash and equivalents at end of period		$	563			$	1,066

See Note 2 for disclosure of supplemental cash flow information.

The accompanying notes are an integral part of Dominion Energy’s Consolidated Financial Statements.

13

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

		Three Months Ended September 30,								Nine Months Ended September 30,
		2026				2025				2026				2025
(millions)
Operating Revenue(1)		$	4,218			$	3,311			$	11,335			$	8,788
Operating Expenses
Electric fuel and other energy-related purchases(1)			1,296				1,071				3,739				2,569
Purchased electric capacity			103				32				246				56
Other operations and maintenance:
Affiliated suppliers			147				127				448				386
Other			597				450				1,591				1,354
Depreciation and amortization			509				418				1,347				1,212
Other taxes			104				93				309				282
Impairment of assets and other charges (benefits)			3				129				157				225
Total operating expenses			2,759				2,320				7,837				6,084
Income from operations			1,459				991				3,498				2,704
Other income (expense)			67				85				221				191
Interest and related charges(1)			312				235				833				729
Income before income tax expense			1,214				841				2,886				2,166
Income tax expense			220				151				519				356
Net Income Including Noncontrolling Interests			994				690				2,367				1,810
Noncontrolling Interests			114				22				267				122
Net Income Attributable to Virginia Power		$	880			$	668			$	2,100			$	1,688

(1)See Note 18 for amounts attributable to affiliates.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

14

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

		Three Months Ended September 30,								Nine Months Ended September 30,
		2026				2025				2026				2025
(millions)
Net income including noncontrolling interests		$	994			$	690			$	2,367			$	1,810
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities(1)			31				(2	)			30				(7	)
Changes in unrealized net gains (losses) on investment securities(2)			(1	)			1				(1	)			1
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities(3)			—				—				(1	)			—
Net realized (gains) losses on investment securities(4)			1				—				1				—
Total other comprehensive income (loss)			31				(1	)			29				(6	)
Comprehensive income including noncontrolling interests			1,025				689				2,396				1,804
Comprehensive income (loss) attributable to noncontrolling interests			114				22				267				122
Comprehensive income attributable to Virginia Power		$	911			$	667			$	2,129			$	1,682

(1)Net of $(11) million and $— million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $(10) million and $2 million tax for the nine months ended September 30, 2026 and 2025, respectively.

(2)Net of $— million and $(1) million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $— million and $(1) million tax for the nine months ended September 30, 2026 and 2025, respectively.

(3)Net of $— million and $— million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $— million and $— million tax for the nine months ended September 30, 2026 and 2025, respectively.

(4)Net of $— million and $— million tax for the three months ended September 30, 2026 and 2025, respectively, and net of $— million and $— million tax for the nine months ended September 30, 2026 and 2025, respectively.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

15

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

		September 30, 2026				December 31, 2025(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents(2)		$	242			$	170
Customer receivables (less allowance for doubtful accounts of $27 and $25)			2,459				1,930
Other receivables (less allowance for doubtful accounts of $3 at both dates)(2)			177				252
Affiliated receivables			1				35
Inventories (average cost method)			1,292				1,250
Derivative assets(3)			43				212
Regulatory assets(2)			1,602				1,110
Other(2)(3)			216				166
Total current assets			6,032				5,125
Investments
Nuclear decommissioning trust funds			5,358				4,864
Other(2)			7				4
Total investments			5,365				4,868
Property, Plant and Equipment
Property, plant and equipment(2)			86,246				80,121
Accumulated depreciation and amortization(2)			(20,127	)			(19,157	)
Total property, plant and equipment, net			66,119				60,964
Deferred Charges and Other Assets
Regulatory assets(2)			4,669				4,526
Other(2)(3)			4,623				3,760
Total deferred charges and other assets			9,292				8,286
Total assets		$	86,808			$	79,243

(1)Virginia Power’s Consolidated Balance Sheet at December 31, 2025 has been derived from the audited Consolidated Balance Sheet at that date.

(2)See Note 14 for amounts attributable to VIEs.

(3)See Note 18 for amounts attributable to affiliates.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

16

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

		September 30, 2026				December 31, 2025(1)
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year(2)		$	1,972			$	1,366
Short-term debt			485				675
Accounts payable(2)			898				821
Payables to affiliates			281				216
Affiliated current borrowings			403				1,173
Accrued interest, payroll and taxes(2)			586				450
Regulatory liabilities			284				374
Other(2)(3)			1,736				1,900
Total current liabilities			6,645				6,975
Long-Term Debt
Long-term debt			23,366				20,651
Securitization bonds(2)			794				883
Other			202				194
Total long-term debt			24,362				21,728
Deferred Credits and Other Liabilities
Deferred income taxes			5,384				4,921
Deferred investment tax credits			602				616
Regulatory liabilities			7,389				6,530
Other(3)			7,781				6,934
Total deferred credits and other liabilities			21,156				19,001
Total liabilities			52,163				47,704
Commitments and Contingencies (see Note 16)
Equity
Common stock – no par(4)			12,937				12,487
Other paid-in capital			999				999
Retained earnings			15,787				13,687
Accumulated other comprehensive income			61				32
Shareholder’s equity			29,784				27,205
Noncontrolling interests			4,861				4,334
Total equity			34,645				31,539
Total liabilities and equity		$	86,808			$	79,243

(1)Virginia Power’s Consolidated Balance Sheet at December 31, 2025 has been derived from the audited Consolidated Balance Sheet at that date.

(2)See Note 14 for amounts attributable to VIEs.

(3)See Note 18 for amounts attributable to affiliates.

(4)500,000 shares authorized; 379,927 and 373,881 shares outstanding at September 30, 2026 and December 31, 2025, respectively.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

17

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

QUARTER-TO-DATE

		Common Stock
		Shares				Amount				Other Paid-In Capital				Retained Earnings				AOCI				Shareholder's Equity				Noncontrolling  Interests				Total Equity
(millions, except for shares)		(thousands)
June 30, 2025			354			$	11,087			$	999			$	13,156			$	23			$	25,265			$	3,657			$	28,922
Net income including     noncontrolling interests															668								668				22				690
Issuance of stock to     Dominion Energy		20					1,400																1,400								1,400
Contributions from     Stonepeak to OSWP																											417				417
Distributions from     OSWP to Stonepeak																											(61	)			(61	)
Other comprehensive     income (loss), net of tax																			(1	)			(1	)							(1	)
Other															1								1								1
September 30, 2025			374			$	12,487			$	999			$	13,825			$	22			$	27,333			$	4,035			$	31,368
June 30, 2026			380			$	12,937			$	999			$	14,907			$	30			$	28,873			$	4,689			$	33,562
Net income including     noncontrolling interests															880								880				114				994
Contributions from     Stonepeak to OSWP																											136				136
Distributions from     OSWP to Stonepeak																											(78	)			(78	)
Other comprehensive     income (loss), net of tax																			31				31								31
September 30, 2026			380			$	12,937			$	999			$	15,787			$	61			$	29,784			$	4,861			$	34,645

18

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

YEAR-TO-DATE

		Common Stock
		Shares				Amount				Other Paid-In Capital				Retained Earnings				AOCI				Shareholder's Equity				Noncontrolling Interests				Total Equity
(millions, except for shares)		(thousands)
December 31, 2024			324			$	8,987			$	1,006			$	12,136			$	28			$	22,157			$	2,939			$	25,096
Net income including     noncontrolling interests															1,688								1,688				122				1,810
Issuance of stock to     Dominion Energy		50					3,500																3,500								3,500
Sale of noncontrolling     interest in OSWP											(7	)											(7	)							(7	)
Contributions from     Stonepeak to OSWP																											1,141				1,141
Distributions from     OSWP to Stonepeak																											(167	)			(167	)
Other comprehensive     income (loss), net of tax																			(6	)			(6	)							(6	)
Other															1								1								1
September 30, 2025			374			$	12,487			$	999			$	13,825			$	22			$	27,333			$	4,035			$	31,368
December 31, 2025			374			$	12,487			$	999			$	13,687			$	32			$	27,205			$	4,334			$	31,539
Net income including     noncontrolling interests															2,100								2,100				267				2,367
Issuance of stock to     Dominion Energy		6					450																450								450
Contributions from     Stonepeak to OSWP																											506				506
Distributions from     OSWP to Stonepeak																											(246	)			(246	)
Other comprehensive     income (loss), net of tax																			29				29								29
September 30, 2026			380			$	12,937			$	999			$	15,787			$	61			$	29,784			$	4,861			$	34,645

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

19

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Nine Months Ended September 30,		2026				2025
(millions)
Operating Activities
Net income including noncontrolling interests		$	2,367			$	1,810
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)			1,471				1,337
Deferred income taxes			284				225
Deferred investment tax credits (benefits)			(15	)			(18	)
Impairment of assets and other charges (benefits)			154				225
Net (gains) losses on nuclear decommissioning trust funds and other investments			(58	)			(65	)
Other adjustments			(76	)			(71	)
Changes in:
Accounts receivable			(402	)			(129	)
Affiliated receivables and payables			99				(32	)
Inventories			(37	)			(66	)
Prepayments and deposits, net			(2	)			(59	)
Deferred fuel expenses, net			(371	)			(464	)
Accounts payable			117				64
Accrued interest, payroll and taxes			135				143
Net realized and unrealized changes related to derivative activities			265				95
Other operating assets and liabilities			298				323
Net cash provided by operating activities			4,229				3,318
Investing Activities
Plant construction and other property additions			(7,039	)			(7,531	)
Purchases of nuclear fuel			(107	)			(147	)
Acquisition of solar development projects			(16	)			(12	)
Proceeds from sales of securities			1,979				1,412
Purchases of securities			(2,054	)			(1,473	)
Other			22				(78	)
Net cash used in investing activities			(7,215	)			(7,829	)
Financing Activities
Issuance (repayment) of short-term debt, net			(190	)			(950	)
Issuance (repayment) of affiliated current borrowings, net			(770	)			(500	)
Issuance and remarketing of long-term debt			4,100				3,172
Repayment and repurchases of long-term debt			(750	)			(572	)
Repayment of securitization bonds			(85	)			(80	)
Proceeds from sale of noncontrolling interest in OSWP			—				(88	)
Contributions from Stonepeak to OSWP			506				1,141
Distributions from OSWP to Stonepeak			(246	)			(167	)
Issuance of common stock			450				3,500
Common dividend payments to parent			—				(407	)
Other			102				27
Net cash provided by financing activities			3,117				5,076
Increase in cash, restricted cash and equivalents			131				565
Cash, restricted cash and equivalents at beginning of period			231				206
Cash, restricted cash and equivalents at end of period		$	362			$	771

See Note 2 for disclosure of supplemental cash flow information.

The accompanying notes are an integral part of Virginia Power’s Consolidated Financial Statements.

20

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1. Nature of Operations

Dominion Energy, headquartered in Richmond, Virginia, provides primarily regulated electricity service in Virginia, North Carolina and South Carolina through its subsidiaries, Virginia Power and DESC, and is one of the nation’s leading developers and operators of regulated offshore wind and solar power and the largest producer of carbon-free electricity in New England. Dominion Energy also has nonregulated operations that include long-term contracted electric generation operations.

Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and North Carolina. Virginia Power is a member of PJM, an RTO, and its electric transmission facilities are integrated into PJM. All of Virginia Power’s stock is owned by Dominion Energy.

Dominion Energy manages its daily operations through three primary operating segments: Dominion Energy Virginia, Dominion Energy South Carolina and Contracted Energy. Virginia Power manages its daily operations through one primary operating segment: Dominion Energy Virginia. The Companies each also report a Corporate and Other segment. See Note 20 for further discussion on the Companies’ operating segments.

Proposed Merger

In May 2026, Dominion Energy entered into the NextEra Energy Merger Agreement pursuant to which the Companies will become wholly-owned subsidiaries of NextEra Energy upon closing of the NextEra Energy Merger, which is expected in the second half of 2027, contingent upon receipt of regulatory approvals and the satisfaction of other closing conditions as discussed below. Under the terms of the NextEra Energy Merger Agreement, at closing each outstanding share of Dominion Energy common stock, other than shares to be cancelled as described in the NextEra Energy Merger Agreement, will be converted into the right to receive (i) its pro rata share of an aggregate amount equal to $360 million in cash, without interest, and (ii) 0.8138 shares of NextEra Energy common stock. The terms of the NextEra Energy Merger Agreement require Dominion Energy to redeem any outstanding Series C Preferred Stock, assuming closing occurs after January 2027, and call for redemption any outstanding variable denomination floating rate demand notes, also referred to as Dominion Energy Reliability InvestmentSM. In addition, Dominion Energy expects to settle any outstanding forward sales contracts under its at-the-market program prior to closing. The NextEra Energy Merger Agreement requires the Companies to obtain the consent of NextEra Energy, which consent cannot be unreasonably withheld, for certain activities, such as the payment by Dominion Energy of dividends in excess of $0.6675 per share each quarter, the issuance of debt or equity securities in excess of a specific amount and certain acquisitions or dispositions.

The completion of the NextEra Energy Merger is subject to customary closing conditions, including, among others, approval by the holders of Dominion Energy common stock of the NextEra Energy Merger Agreement and the applicable plan of merger, approval by NextEra Energy shareholders of the issuance of NextEra Energy common stock in connection with the NextEra Energy Merger, expiration or termination of the applicable waiting period under the HSR, receipt of specified regulatory approvals, including the obtaining by Dominion Energy and NextEra Energy of consents and approvals required from the (i) FERC, (ii) NRC (iii) Virginia Commission, (iv) North Carolina Commission and (v) South Carolina Commission, approval for listing on the NYSE of the NextEra Energy common stock to be issued in the NextEra Energy Merger, continued effectiveness of the registration statement on Form S-4 filed by NextEra Energy in connection with the NextEra Energy Merger, accuracy of the parties’ representations and warranties, compliance with covenants, and the absence of a material adverse effect on either Dominion Energy or NextEra Energy. In July 2026, Dominion Energy and NextEra Energy filed for review and approval with FERC, the NRC and the Virginia, North Carolina and South Carolina Commissions. Dominion Energy and NextEra Energy received shareholder approvals in September 2026 and filed for clearance under the HSR in October 2026. The July filings with the Virginia, North Carolina and South Carolina Commissions included proposals for an aggregate amount of $2.25 billion of customer rate credits, including approximately $1.78 billion to customers in Virginia, for utility customers allocated based on usage and payable over two years following closing along with an aggregate increase in charitable commitments of $10 million per year for five years following closing with such amounts to be funded by NextEra Energy. In September 2026, Dominion Energy and NextEra Energy filed an alternative proposal with the Virginia Commission which would extend the customer rate credits for residential customers to four years through the elimination of rate credits for certain large load customers and an additional approximately $90 million of shareholder funding. In addition, Dominion Energy and NextEra Energy proposed for shareholders to fund an additional $100 million to a customer assistance program through 2038, contribute $100 million to a workforce development fund and to fund a new corporate office building in Richmond, Virginia. Further, Dominion Energy and NextEra Energy proposed a five-year $1 billion annual supplier program in Virginia, to host an annual global energy summit and to maintain existing headcount and add new jobs in Virginia.

The NextEra Energy Merger Agreement contains customary termination rights for each of Dominion Energy and NextEra Energy, including if the NextEra Energy Merger has not been consummated by November 2027, subject to extension to August 2028 in certain circumstances, if either of the required shareholder approvals had not been obtained, or due to certain breaches of the NextEra Energy Merger Agreement. In certain circumstances in connection with or following termination of the NextEra Energy Merger Agreement, Dominion Energy will be required to pay NextEra

21

Energy a termination fee of $2.24 billion. In comparable circumstances, NextEra Energy will be required to pay Dominion Energy a termination fee of $6.52 billion. In other specified circumstances where the NextEra Energy Merger Agreement is terminated due to the failure of one or more specified conditions relating to or involving certain regulatory matters, NextEra Energy will be required to pay Dominion Energy a termination fee of $4.83 billion.

Note 2. Significant Accounting Policies

As permitted by the rules and regulations of the SEC, the Companies’ accompanying unaudited Consolidated Financial Statements contain certain condensed financial information and exclude certain footnote disclosures normally included in annual audited consolidated financial statements prepared in accordance with GAAP. These unaudited Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and Notes in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position at September 30, 2026, their results of operations and changes in equity for the three and nine months ended September 30, 2026 and 2025 and their cash flows for the nine months ended September 30, 2026 and 2025. Such adjustments are normal and recurring in nature unless otherwise noted.

The Companies make certain estimates and assumptions in preparing their Consolidated Financial Statements in accordance with GAAP. These estimates and assumptions affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses and cash flows for the periods presented. Actual results may differ from those estimates.

The Companies’ accompanying unaudited Consolidated Financial Statements include, after eliminating intercompany transactions and balances, their accounts, those of their respective majority-owned subsidiaries and non-wholly-owned entities in which they have a controlling financial interest. For certain partnership structures, income is allocated based on the liquidation value of the underlying contractual arrangements. Stonepeak’s 50% ownership interest in OSWP is reflected as noncontrolling interest in the Companies’ Consolidated Financial Statements.

The results of operations for interim periods are not necessarily indicative of the results expected for the full year. Information for quarterly periods is affected by seasonal variations in sales, rate changes, electric fuel and other energy-related purchases, purchased gas expenses and other factors.

Certain amounts in the Companies’ 2025 Consolidated Financial Statements have been reclassified to conform to the 2026 presentation for comparative purposes; however, such reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows.

Amounts disclosed for Dominion Energy are inclusive of Virginia Power, where applicable. There have been no significant changes from Note 2 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, with the exception of the items described below.

Cash, Restricted Cash and Equivalents

Restricted Cash and Equivalents

The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the nine months ended September 30, 2026 and 2025:

		Cash, Restricted Cash and Equivalents at End of Period								Cash, Restricted Cash and Equivalents at Beginning of Period
		September 30, 2026				September 30, 2025				December 31, 2025				December 31, 2024
(millions)
Dominion Energy
Cash and cash     equivalents		$	435			$	932			$	250			$	310
Restricted cash and    equivalents(1)(2)			128				134				93				55
Cash, restricted cash    and equivalents shown    in the Consolidated    Statements of Cash Flows		$	563			$	1,066			$	343			$	365
Virginia Power
Cash and cash     equivalents		$	242			$	646			$	170			$	160
Restricted cash and    equivalents(1)(2)			120				125				61				46
Cash, restricted cash    and equivalents shown    in the Consolidated    Statements of Cash Flows		$	362			$	771			$	231			$	206

(1)Includes $104 million, $115 million, $51 million and $41 million at VPFS attributable to VIEs at September 30, 2026, September 30, 2025, December 31, 2025 and December 31, 2024, respectively.

(2)Restricted cash and equivalents balances are presented within other current assets in the Companies’ Consolidated Balance Sheets.

Supplemental Cash Flow Information

The following table provides supplemental disclosure of cash flow information related to Dominion Energy:

Nine Months Ended September 30,		2026				2025
(millions)
Significant noncash investing    and financing activities:
Accrued capital expenditures		$	1,320			$	891
Leases(1)			366				315

(1)Includes $64 million and $281 million of financing leases entered in during the nine months ended September 30, 2026 and 2025, respectively, and $302 million and $34 million of operating leases entered in during the nine months ended September 30, 2026 and 2025, respectively.

22

The following table provides supplemental disclosure of cash flow information related to Virginia Power:

Nine Months Ended September 30,		2026				2025
(millions)
Significant noncash investing    and financing activities:
Accrued capital expenditures		$	1,193			$	727
Leases(1)			448				317

(1)Includes $54 million and $62 million of financing leases entered in during the nine months ended September 30, 2026 and 2025, respectively, $300 million and $255 million of operating leases entered in during the nine months ended September 30, 2026 and 2025, respectively, and $94 million for modifications of operating leases during the nine months ended September 30, 2026.

Asset Retirement Obligations

In the second quarter of 2026, Dominion Energy revised its estimated cash flow projections associated with the recovery of spent nuclear fuel costs for its AROs associated with the decommissioning of Millstone, which resulted in a decrease of $208 million. Dominion Energy recorded a benefit associated with Millstone Unit 1 of $195 million ($142 million after-tax) within impairment of assets and other charges (benefits) in its Consolidated Statements of Income (reflected in the Corporate and Other segment) for the nine months ended September 30, 2026.

Also in the second quarter of 2026, Dominion Energy revised its estimated cash flow projections for its AROs to reflect updated information concerning two facilities related to CCR remediation. As a result, Dominion Energy recorded a $203 million increase to its AROs with a corresponding increase to regulatory assets.

Note 3. Operating Revenue

The Companies’ operating revenue consists of the following:

		Dominion Energy																Virginia Power
		Quarter-to-Date								Year-to-Date								Quarter-to-Date								Year-to-Date
Period Ended September 30,		2026				2025				2026				2025				2026				2025				2026				2025
(millions)
Regulated electric sales:
Residential		$	2,157			$	1,712			$	5,527			$	4,628			$	1,631			$	1,279			$	4,287			$	3,494
Commercial			1,404				1,164				3,567				3,006				1,092				890				2,778				2,284
High load(1)			706				503				2,156				1,308				706				503				2,156				1,308
Industrial			276				205				660				546				147				90				307				224
Government and other retail			384				344				1,101				954				363				324				1,046				900
Wholesale			60				54				174				135				39				41				132				107
Nonregulated electric sales			343				295				1,035				905				77				40				152				105
Regulated gas sales:
Residential			34				32				268				249
Commercial			27				24				111				105
Other			7				7				23				39
Regulated gas transportation and storage			11				10				32				26
Other regulated revenue			107				100				243				243				102				96				228				230
Other nonregulated revenues(2)(3)(4)			76				60				242				169				22				16				67				38
Total operating revenue from     contracts with customers			5,592				4,510				15,139				12,313				4,179				3,279				11,153				8,690
Other revenues(2)(5)			25				17				(23	)			100				39				32				182				98
Total operating revenue		$	5,617			$	4,527			$	15,116			$	12,413			$	4,218			$	3,311			$	11,335			$	8,788

(1)Represents customers in Virginia, including certain data centers, with actual or anticipated forecast demand of 25 MW or higher and annual load factor of 75% or higher.

(2)See Note 18 for amounts attributable to affiliates.

(3)Includes sales of renewable energy credits of $28 million and $8 million for the three months ended September 30, 2026 and 2025, respectively, and $78 million and $23 million for the nine months ended September 30, 2026 and 2025, respectively, at Dominion Energy and $7 million and $4 million for the three months ended September 30, 2026 and 2025, respectively, and $18 million and $10 million for the nine months ended September 30, 2026 and 2025, respectively, at Virginia Power.

(4)Includes revenue from transition services agreements of $13 million and $23 million for the three months ended September 30, 2026 and 2025, respectively, and $61 million and $74 million for the nine months ended September 30, 2026 and 2025, respectively, at Dominion Energy.

(5)Includes alternative revenue of $38 million and $35 million for the three months ended September 30, 2026 and 2025, respectively, and $174 million and $117 million for the nine months ended September 30, 2026 and 2025, respectively, at both Dominion Energy and Virginia Power.

Neither Dominion Energy nor Virginia Power have any amounts for revenue to be recognized in the future on multi-year contracts in place at September 30, 2026.

At September 30, 2026 and December 31, 2025, Dominion Energy’s contract liability balances were $41 million and $45 million, respectively. At September 30, 2026 and December 31, 2025, Virginia Power’s contract liability balances were $35 million and $38 million, respectively. The Companies’ contract liabilities are recorded in other current liabilities and other deferred credits and other liabilities in the Consolidated Balance Sheets.

23

The Companies recognize revenue as they fulfill their obligations to provide service to their customers. During the nine months ended September 30, 2026 and 2025, Dominion Energy recognized revenue of $43 million and $50 million, respectively, from the beginning contract liability balances. During the nine months ended September 30, 2026 and 2025, Virginia Power recognized $38 million and $46 million, respectively, from the beginning contract liability balances.

Note 4. Income Taxes

Other than the following matters, there have been no significant developments regarding the Companies’ provision for income taxes, tax-related assets and liabilities and/or unrecognized tax benefits disclosed in Note 5 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

For continuing operations including noncontrolling interests for the nine months ended September 30, 2026, the statutory U.S. federal income tax rate reconciles to the Companies’ effective income tax rate as follows:

		Dominion Energy									Virginia Power
(millions, except percentages)		Amount				Rate					Amount				Rate
U.S. federal statutory tax		$	583				21.0				$	606				21.0		%
State and local income taxes, net of federal income tax effect(1)			89				3.2					112				3.9
Tax credits:
Production tax credits(2)			(154	)			(5.5	)				(47	)			(1.6	)
Investment tax credit amortization			(71	)			(2.5	)				(41	)			(1.4	)
Nontaxable or nondeductible items:
Regulatory deferrals:
Reversal of excess deferred income taxes			(56	)			(2.0	)				(36	)			(1.3	)
AFUDC—equity			(26	)			(0.9	)				(27	)			(0.9	)
Absence of tax on noncontrolling interest			(59	)			(2.1	)				(59	)			(2.1	)
Other adjustments:
Qualified nuclear decommissioning trust net gains (losses)			82				3.0					12				0.4
Other			(3	)			(0.3	)				(1	)			—
Effective tax(3)		$	385				13.9		%		$	519				18.0		%

(1)State taxes in Virginia make up the majority (greater than 50%) of the tax effect in this category.

(2)Dominion Energy production tax credits include a $94 million income tax benefit for the clean energy fuel production tax credit.

(3)The Companies had no adjustments related to the following disclosure categories: foreign tax effects, effects of changes in tax law or rates enacted in the current period and effects of cross-border tax laws.

For continuing operations, including noncontrolling interests for the nine months ended September 30, 2025, the statutory U.S. federal income tax rate reconciles to the Companies’ effective income tax rate as follows:

		Dominion Energy				Virginia Power
U.S. federal statutory tax rate		21.0%				21.0%
Increases (reductions) resulting from:
State taxes, net of federal benefit			3.9				4.4
Investment tax credits			(2.4	)			(0.8	)
Production tax credits(1)			(4.7	)			(4.1	)
Reversal of excess deferred income taxes			(1.6	)			(1.7	)
Qualified nuclear decommissioning trust net gains (losses)			2.5				0.5
Remeasurements and settlements of uncertain tax positions			(1.0	)			—
AFUDC—equity			(0.7	)			(1.0	)
Absence of tax on noncontrolling interest			(1.2	)			(1.8	)
Other, net			(0.1	)			(0.1	)
Effective tax rate			15.7	%			16.4	%

(1)Dominion Energy and Virginia Power production tax credits include a $66 million income tax benefit for the nuclear production tax credit. Dominion Energy production tax credits also include a $50 million income tax benefit for the clean fuel production tax credit.

During the second quarter of 2026, Dominion Energy determined that it is expected to be subject to the corporate alternative minimum tax in 2026. At September 30, 2026, Dominion Energy’s Consolidated Balance Sheet reflects a corporate alternative minimum tax liability of $14 million, net of tax credit utilization, along with corresponding deferred tax assets related to corporate alternative minimum tax credit carryforwards, which management expects to fully utilize in future periods. The ultimate impact of the corporate alternative minimum tax remains subject to pending guidance and interpretations, which could materially impact the Companies’ results of operations, financial condition and/or cash flows.

During the nine months ended September 30, 2026, Dominion Energy and Virginia Power entered into agreements with third parties to transfer tax credits generated in 2025 and 2026. Dominion Energy received cash proceeds of $71 million related to the transfer of tax credits through September 30, 2026. In addition, Virginia Power expects to receive an additional $22 million in the fourth quarter of 2026 which is reflected in other receivables in the Companies’ Consolidated Balance Sheets at September 30, 2026.

24

Note 5. Earnings Per Share

The following table presents the calculation of Dominion Energy’s basic and diluted EPS:

		Quarter-to-Date								Year-to-Date
Period Ended September 30,		2026				2025				2026				2025
(millions, except EPS)
Net income attributable to Dominion Energy from continuing operations		$	1,161			$	1,006			$	2,124			$	2,431
Preferred stock dividends (see Note 15)			(11	)			(11	)			(33	)			(33	)
Net income attributable to Dominion Energy from continuing operations - Basic & Diluted			1,150				995				2,091				2,398
Net income (loss) attributable to Dominion Energy from discontinued operations - Basic &    Diluted		$	(1	)		$	—			$	(3	)		$	—
Average shares of common stock outstanding - Basic			879.5				853.5				879.3				852.8
Net effect of dilutive securities(1)			2.6				1.9				2.1				0.8
Average shares of common stock outstanding - Diluted			882.1				855.4				881.4				853.6
EPS from continuing operations - Basic		$	1.31			$	1.17			$	2.37			$	2.81
EPS from discontinued operations - Basic			—				—				—				—
EPS attributable to Dominion Energy - Basic		$	1.31			$	1.17			$	2.37			$	2.81
EPS from continuing operations - Diluted		$	1.30			$	1.16			$	2.37			$	2.81
EPS from discontinued operations - Diluted			—				—				—				—
EPS attributable to Dominion Energy - Diluted		$	1.30			$	1.16			$	2.37			$	2.81

(1)Dilutive securities for the three months ended September 30, 2026, consists of forward sales agreements entered into the second and third quarters of 2025 and the first quarter of 2026 (applying the treasury stock method). Dilutive securities for the nine months ended September 30, 2026, consists of forward sales agreements entered into in the second and third quarters of 2025 and certain forward sales agreements entered into the first and second quarters of 2026 (applying the treasury stock method). Additionally, dilutive securities for the three months ended September 30, 2025, consists of forward sales agreements entered into in the first, second and third quarters of 2025 and the third and fourth quarters of 2024 (applying the treasury stock method). Dilutive securities for nine months ended September 30, 2025, consists of forward sales agreements entered into the second and third quarters of 2025 and certain forward sales agreements entered into in the first quarter of 2025 and the third and fourth quarters of 2024 (applying the treasury stock method).

Forward sales agreements entered into the second quarter of 2026 were potentially dilutive securities but were excluded from the calculation of diluted EPS from continuing operations for the three months ended September 30, 2026, and certain of the forward sales agreements entered into the first and second quarters of 2026 were potentially dilutive securities but were excluded from the calculation of diluted EPS from continuing operations for the nine months ended September 30, 2026 as the dilutive stock price threshold was not met. Certain of the forward sales agreements entered into in the first quarter of 2025 and the third and fourth quarters of 2024 were potentially dilutive securities, but were excluded from the calculation of diluted EPS from continuing operations for the nine months ended September 30, 2025 as the dilutive stock price threshold was not met.

25

Note 6. Accumulated Other Comprehensive Income (Loss)

Dominion Energy

The following tables present Dominion Energy’s changes in AOCI (net of tax) and reclassifications out of AOCI by component:

		Total Derivative-Hedging Activities(1)				Investment Securities				Pension and other postretirement benefit costs(2)				Total
(millions)
Three Months Ended September 30, 2026
Beginning balance		$	(154	)		$	(1	)		$	21			$	(134	)
Beginning balance, tax			39				—				(5	)			34
Beginning balance, net of tax			(115	)			(1	)			16				(100	)
Other comprehensive income (loss) before     reclassifications: gains (losses)			56				(3	)			—				53
Amounts reclassified from AOCI: (gains) losses
Interest and related charges			8												8
Other income (expense)							2				(3	)			(1	)
Total			8				2				(3	)			7
Income tax expense (benefit)			(2	)			(1	)			1				(2	)
Total, net of tax			6				1				(2	)			5
Net current period other comprehensive income (loss)			62				(2	)			(2	)			58
Ending balance, net of tax			(53	)			(3	)			14				(42	)
Ending balance, tax			18				1				(4	)			15
Ending balance		$	(71	)		$	(4	)		$	18			$	(57	)
Three Months Ended September 30, 2025
Beginning balance		$	(230	)		$	3			$	32			$	(195	)
Beginning balance, tax			58				—				(8	)			50
Beginning balance, net of tax			(172	)			3				24				(145	)
Other comprehensive income (loss) before     reclassifications: gains (losses)			(3	)			6				—				3
Amounts reclassified from AOCI: (gains) losses
Interest and related charges			10												10
Other income (expense)							(1	)			(3	)			(4	)
Total			10				(1	)			(3	)			6
Income tax expense (benefit)			(3	)			—				—				(3	)
Total, net of tax			7				(1	)			(3	)			3
Net current period other comprehensive income (loss)			4				5				(3	)			6
Ending balance, net of tax			(168	)			8				21				(139	)
Ending balance, tax			57				(5	)			(7	)			45
Ending balance		$	(225	)		$	13			$	28			$	(184	)

(1)Comprised entirely of interest rate derivative hedging activities.

(2)Comprised entirely of prior service cost.

26

		Total Derivative-Hedging Activities(1)				Investment Securities				Pension and other postretirement benefit costs(2)				Total
(millions)
Nine Months Ended September 30, 2026
Beginning balance		$	(183	)		$	—			$	26			$	(157	)
Beginning balance, tax			46				—				(7	)			39
Beginning balance, net of tax			(137	)			—				19				(118	)
Other comprehensive income (loss) before     reclassifications: gains (losses)			65				(4	)			—				61
Amounts reclassified from AOCI: (gains) losses
Interest and related charges			25												25
Other income (expense)							2				(8	)			(6	)
Total			25				2				(8	)			19
Income tax expense (benefit)			(6	)			(1	)			3				(4	)
Total, net of tax			19				1				(5	)			15
Net current period other comprehensive income (loss)			84				(3	)			(5	)			76
Ending balance, net of tax			(53	)			(3	)			14				(42	)
Ending balance, tax			18				1				(4	)			15
Ending balance		$	(71	)		$	(4	)		$	18			$	(57	)
Nine Months Ended September 30, 2025
Beginning balance		$	(229	)		$	(19	)		$	38			$	(210	)
Beginning balance, tax			58				9				(9	)			58
Beginning balance, net of tax			(171	)			(10	)			29				(152	)
Other comprehensive income (loss) before     reclassifications: gains (losses)			(19	)			15				—				(4	)
Amounts reclassified from AOCI: (gains) losses
Interest and related charges			30												30
Other income (expense)							4				(9	)			(5	)
Total			30				4				(9	)			25
Income tax expense (benefit)			(8	)			(1	)			1				(8	)
Total, net of tax			22				3				(8	)			17
Net current period other comprehensive income (loss)			3				18				(8	)			13
Ending balance, net of tax			(168	)			8				21				(139	)
Ending balance, tax			57				(5	)			(7	)			45
Ending balance		$	(225	)		$	13			$	28			$	(184	)

(1) Comprised entirely of interest rate derivative hedging activities.

(2) Comprised entirely of prior service cost.

27

Virginia Power

The following tables present Virginia Power’s changes in AOCI (net of tax) and reclassifications out of AOCI by component:

		Total Derivative-Hedging Activities(1)				Investment Securities				Total
(millions)
Three Months Ended September 30, 2026
Beginning balance		$	40			$	—			$	40
Beginning balance, tax			(10	)			—				(10	)
Beginning balance, net of tax			30				—				30
Other comprehensive income (loss) before     reclassifications: gains (losses)			31				(1	)			30
Amounts reclassified from AOCI: (gains) losses
Other income (expense)							1				1
Total			—				1				1
Income tax expense (benefit)			—				—				—
Total, net of tax			—				1				1
Net current period other comprehensive income (loss)			31				—				31
Ending balance, net of tax			61				—				61
Ending balance, tax			(21	)			—				(21	)
Ending balance		$	82			$	—			$	82
Three Months Ended September 30, 2025
Beginning balance		$	31			$	(1	)		$	30
Beginning balance, tax			(8	)			1				(7	)
Beginning balance, net of tax		23					—			23
Other comprehensive income (loss) before     reclassifications: gains (losses)			(2	)			1				(1	)
Amounts reclassified from AOCI: (gains) losses											—
Total			—				—				—
Income tax expense (benefit)			—				—				—
Total, net of tax			—				—				—
Net current period other comprehensive income (loss)			(2	)			1				(1	)
Ending balance, net of tax			21				1				22
Ending balance, tax			(7	)			—				(7	)
Ending balance		$	28			$	1			$	29

(1)Comprised entirely of interest rate derivative hedging activities.

28

		Total Derivative-Hedging Activities(1)				Investment Securities				Total
(millions)
Nine Months Ended September 30, 2026
Beginning balance		$	43			$	—			$	43
Beginning balance, tax			(11	)			—				(11	)
Beginning balance, net of tax			32				—				32
Other comprehensive income (loss) before     reclassifications: gains (losses)			30				(1	)			29
Amounts reclassified from AOCI: (gains) losses
Interest and related charges			(1	)							(1	)
Other income (expense)							1				1
Total			(1	)			1				—
Income tax expense (benefit)			—				—				—
Total, net of tax			(1	)			1				—
Net current period other comprehensive income (loss)			29				—				29
Ending balance, net of tax			61				—				61
Ending balance, tax			(21	)			—				(21	)
Ending balance		$	82			$	—			$	82
Nine Months Ended September 30, 2025
Beginning balance		$	38			$	(1	)		$	37
Beginning balance, tax			(10	)			1				(9	)
Beginning balance, net of tax			28				—				28
Other comprehensive income (loss) before     reclassifications: gains (losses)			(7	)			1				(6	)
Amounts reclassified from AOCI: (gains) losses
Total			—				—				—
Income tax expense (benefit)			—				—				—
Total, net of tax			—				—				—
Net current period other comprehensive income (loss)			(7	)			1				(6	)
Ending balance, net of tax			21				1				22
Ending balance, tax			(7	)			—				(7	)
Ending balance		$	28			$	1			$	29

(1) Comprised entirely of interest rate derivative hedging activities.

Note 7. Fair Value Measurements

The Companies’ fair value measurements are made in accordance with the policies discussed in Note 2 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. See Note 8 for additional information about the Companies’ derivatives and hedge accounting activities.

The Companies enter into certain physical and financial forwards, futures and options, which are considered Level 3 as they have one or more inputs that are not observable and are significant to the valuation. The discounted cash flow method is used to value Level 3 physical and financial forwards and futures contracts. An option model is used to value Level 3 physical options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. The inputs into the option models are the forward market prices, implied price volatilities, risk-free rate of return, the option expiration dates, the option strike prices, the original sales prices and volumes. For Level 3 fair value measurements, certain forward market prices, implied price volatilities and credit spreads are considered unobservable.

29

The following table presents the Companies’ quantitative information about Level 3 fair value measurements at September 30, 2026. The range and weighted-average are presented in dollars for market price inputs and percentages for price volatility and credit spreads.

							Dominion Energy										Virginia Power
			Valuation Techniques		Unobservable Input		Fair Value (millions)				Range		Weighted -average(1)				Fair Value (millions)				Range		Weighted -average(1)
Assets
Physical and financial forwards:
Natural gas(2)			Discounted cash flow		Market price (per Dth)(3)		$	64			(2) - 12			3			$	64			(2) - 2			(1	)
FTRs			Discounted cash flow		Market price (per MWh)(3)			15			1 - 36			13				15			1 - 36			13
Electricity			Discounted cash flow		Market price (per MWh)(3)			351			37 - 136			65
Physical options:
Natural gas(2)			Option model		Market price (per Dth)(3)			323			1 - 20			4				9			3 - 20			8
					Credit spread(4)						0% - 2%			1	%
					Price volatility(5)						2% - 80%			64	%						14% - 71%			47	%
Total assets							$	753									$	88
Liabilities
Physical and financial forwards:
FTRs			Discounted cash flow		Market price (per MWh)(3)			24			(19) - 36			11				24			(19) - 36			11
Electricity			Discounted cash flow		Market price (per MWh)(3)			91			36 - 169			76
Physical options:
Natural gas(2)			Option model		Market price (per Dth)(3)			9			2 - 8			4				9			2 - 8			4
					Credit spread(4)						1% - 2%			1	%						1% - 2%			1	%
					Price volatility(5)						56% - 79%			64	%						56% - 79%			64	%
Total liabilities							$	124									$	33

(1)Averages weighted by volume.

(2)Includes basis.

(3)Represents market prices beyond defined terms for Levels 1 and 2.

(4)Represents credit spreads unrepresented in published markets.

(5)Represents volatilities unrepresented in published markets.

Sensitivity of the fair value measurements to changes in the significant unobservable inputs is as follows:

Significant Unobservable Inputs		Position		Change to Input		Impact on Fair Value Measurement
Market price		Buy		Increase (decrease)		Gain (loss)
Market price		Sell		Increase (decrease)		Loss (gain)
Credit spread		Asset		Increase (decrease)		Loss (gain)
Credit spread		Liability		Increase (decrease)		Gain (loss)
Price volatility		Buy		Increase (decrease)		Gain (loss)
Price volatility		Sell		Increase (decrease)		Loss (gain)

Nonrecurring Fair Value Measurements

See Note 10 for information regarding impairment charges recorded by Dominion Energy associated with certain nonregulated solar generation facilities and nonregulated renewable natural gas facilities.

30

Recurring Fair Value Measurements

The following table presents the Companies’ assets and liabilities that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions:

		Dominion Energy																Virginia Power
		Level 1				Level 2				Level 3				Total				Level 1				Level 2				Level 3				Total
(millions)
September 30, 2026
Assets
Derivatives:
Commodity		$	1			$	107			$	753			$	861			$	1			$	70			$	88			$	159
Interest rate			—				547				—				547				—				480				—				480
Foreign currency exchange rate			—				2				—				2				—				2				—				2
Investments(1):
Equity securities:
U.S.			6,996				—				—				6,996				3,584				—				—				3,584
International			187				—				—				187				100				—				—				100
Fixed income:
Corporate debt instruments			—				135				—				135				—				124				—				124
Government securities			146				223				—				369				102				126				—				228
Private debt funds – liquid investments			—				313				—				313				—				177				—				177
Cash equivalents and other			53				—				—				53				—				—				—				—
Total assets		$	7,383			$	1,327			$	753			$	9,463			$	3,787			$	979			$	88			$	4,854
Liabilities
Derivatives:
Commodity		$	—			$	291			$	124			$	415			$	—			$	13			$	33			$	46
Interest rate			—				—				—				—				—				—				—				—
Foreign currency exchange rate			—				9				—				9				—				9				—				9
Total liabilities		$	—			$	300			$	124			$	424			$	—			$	22			$	33			$	55
December 31, 2025
Assets
Derivatives:
Commodity		$	—			$	87			$	642			$	729			$	—			$	49			$	208			$	257
Interest rate			—				201				—				201				—				197				—				197
Foreign currency exchange rate			—				28				—				28				—				28				—				28
Investments(1):
Equity securities:
U.S.			6,215				—				—				6,215				3,154				—				—				3,154
International			168				—				—				168				96				—				—				96
Fixed income:
Corporate debt instruments			—				10				—				10				—				—				—				—
Government securities			418				74				—				492				332				—				—				332
Cash equivalents and other			46				—				—				46				—				—				—				—
Total assets		$	6,847			$	400			$	642			$	7,889			$	3,582			$	274			$	208			$	4,064
Liabilities
Derivatives:
Commodity		$	—			$	201			$	15			$	216			$	—			$	13			$	—			$	13
Interest rate			—				19				—				19				—				8				—				8
Foreign currency exchange rate			—				10				—				10				—				10				—				10
Total liabilities		$	—			$	230			$	15			$	245			$	—			$	31			$	—			$	31

(1)Includes investments held in the nuclear decommissioning trusts and rabbi trusts. Excludes $2.1 billion and $2.3 billion for Dominion Energy, inclusive of $1.1 billion and $1.3 billion at Virginia Power, at September 30, 2026 and December 31, 2025, respectively, of assets measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.

31

The following table presents the net change in the Companies’ assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category:

		Dominion Energy																Virginia Power
		Quarter-to-Date								Year-to-Date								Quarter-to-Date								Year-to-Date
Period Ended September 30,		2026				2025				2026				2025				2026				2025				2026				2025
(millions)
Beginning balance		$	930			$	414			$	627			$	384			$	315			$	179			$	208			$	68
Total realized and unrealized gains (losses):
Included in earnings:
Operating revenue			(54	)			(24	)			(84	)			(14	)
Purchased electric capacity			—				—				(7	)		—					—				—				(7	)			—
Electric fuel and other energy-related purchases			(46	)			115				206				233				(58	)			106				186				222
Purchased gas			(3	)			—				(3	)		—
Included in regulatory assets/liabilities			(210	)			33				(47	)			76				(251	)			(11	)			(151	)			102
Settlements			21				(126	)			(275	)			(275	)			58				(106	)			(183	)			(232	)
Purchases			—				—				221				8				—				—				11				8
Sales			(9	)			—				(9	)			—				(9	)			—				(9	)			—
Transfers out of Level 3			—				(1	)			—				(1	)
Ending balance		$	629			$	411			$	629			$	411			$	55			$	168			$	55			$	168

Dominion Energy had $(53) million and $(84) million of unrealized gains (losses) included in earnings in the Level 3 fair value category related to assets/liabilities still held at the reporting date for the three and nine months ended September 30, 2026, respectively, and $(24) million and $(14) million of unrealized gains (losses) included in earnings in the Level 3 fair value category related to assets/liabilities still held at the reporting date for the three and nine months ended September 30, 2025, respectively. Virginia Power had no unrealized gains and losses included in earnings in the Level 3 fair value category related to assets/liabilities still held at the reporting date for both the three and nine months ended September 30, 2026 and 2025.

Fair Value of Financial Instruments

Substantially all of the Companies’ financial instruments are recorded at fair value, with the exception of the instruments described below, which are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of cash, restricted cash and equivalents, customer and other receivables, affiliated receivables, short-term debt, affiliated current borrowings, payables to affiliates and accounts payable are representative of fair value because of the short-term nature of these instruments. For the Companies’ financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:

		Dominion Energy								Virginia Power
		Carrying Amount				Estimated Fair Value(1)				Carrying Amount				Estimated Fair Value(1)
(millions)
September 30, 2026
Long-term debt(2)		$	42,372			$	38,066			$	25,115			$	22,114
Securitization     bonds(3)			970				960				970				960
Junior subordinated     notes(2)			7,461				7,312
December 31, 2025
Long-term debt(2)		$	38,897			$	37,481			$	21,800			$	20,593
Securitization     bonds(3)			1,054				1,076				1,054				1,076
Junior subordinated     notes(2)			5,978				6,217

(1)Fair value is estimated using market prices, where available, and interest rates currently available for issuance of debt with similar terms and remaining maturities. All fair value measurements are classified as Level 2. The carrying amount of debt issuances with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

(2)Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs and discount or premium. There were no fair value hedges associated with fixed-rate debt at September 30, 2026 and December 31, 2025.

(3)Carrying amount includes current portions included in securities due within one year.

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Note 8. Derivatives and Hedge Accounting Activities

The Companies’ accounting policies, objectives and strategies for using derivative instruments and cash collateral or other instruments under master netting or similar arrangements are discussed in Notes 2 and 7 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. See Note 7 for additional information about fair value measurements and associated valuation methods for derivatives. See Note 17 for additional information regarding credit-related contingent features for the Companies’ derivative instruments.

Balance Sheet Presentation

The tables below present the Companies’ derivative asset and liability balances by type of financial instrument, if the gross amounts recognized in their Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid:

		Dominion Energy Gross Amounts Not Offset in the Consolidated Balance Sheet																Virginia Power Gross Amounts Not Offset in the Consolidated Balance Sheet
		Gross Assets Presented in the Consolidated Balance Sheet(1)				Financial Instruments				Cash Collateral Received				Net Amounts				Gross Assets Presented in the Consolidated Balance Sheet(1)				Financial Instruments				Cash Collateral Received				Net Amounts
(millions)
September 30, 2026
Commodity contracts:
Over-the-counter		$	473			$	15			$	—			$	458			$	149			$	15			$	—			$	134
Exchange			38				37				—				1				1				—				—				1
Interest rate contracts:
Over-the-counter			547				—				—				547				480				—				—				480
Foreign currency exchange rate contracts:
Over-the-counter			2				2				—				—				2				2				—				—
Total derivatives, subject to a master    netting or similar arrangement		$	1,060			$	54			$	—			$	1,006			$	632			$	17			$	—			$	615
December 31, 2025
Commodity contracts:
Over-the-counter		$	464			$	4			$	—			$	460			$	239			$	4			$	—			$	235
Exchange			48				48				—				—				—				—				—				—
Interest rate contracts:
Over-the-counter			201				5				—				196				197				4				—				193
Foreign currency exchange rate contracts:
Over-the-counter			28				8				—				20				28				8				—				20
Total derivatives, subject to a master    netting or similar arrangement		$	741			$	65			$	—			$	676			$	464			$	16			$	—			$	448

(1)Excludes derivative assets of $350 million and $217 million at Dominion Energy and $9 million and $18 million at Virginia Power at September 30, 2026 and December 31, 2025, respectively, which are not subject to master netting or other similar arrangements.

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		Dominion Energy Gross Amounts Not Offset in the Consolidated Balance Sheet																Virginia Power Gross Amounts Not Offset in the Consolidated Balance Sheet
		Gross Liabilities Presented in the Consolidated Balance Sheet(1)				Financial Instruments				Cash Collateral Paid				Net Amounts				Gross Liabilities Presented in the Consolidated Balance Sheet(1)				Financial Instruments				Cash Collateral Paid				Net Amounts
(millions)
September 30, 2026
Commodity contracts:
Over-the-counter		$	89			$	15			$	—			$	74			$	39			$	15			$	—			$	24
Exchange			320				37				283				—				—				—				—				—
Interest rate contracts:
Over-the-counter			—				—				—				—				—				—				—				—
Foreign currency exchange rate contracts:
Over-the-counter			9				2				—				7				9				2				—				7
Total derivatives, subject to a master   netting or similar arrangement		$	418			$	54			$	283			$	81			$	48			$	17			$	—			$	31
December 31, 2025
Commodity contracts:
Over-the-counter		$	38			$	4			$	—			$	34			$	6			$	4			$	—			$	2
Exchange			173				48				125				—				—				—				—				—
Interest rate contracts:
Over-the-counter			19				5				—				14				8				4				—				4
Foreign currency exchange rate contracts:
Over-the-counter			10				8				—				2				10				8				—				2
Total derivatives, subject to a master   netting or similar arrangement		$	240			$	65			$	125			$	50			$	24			$	16			$	—			$	8

(1)Excludes derivative liabilities of $6 million and $5 million at Dominion Energy and $7 million and $7 million at Virginia Power at September 30, 2026 and December 31, 2025, respectively, which are not subject to master netting or other similar arrangements.

Volumes

The following table presents the volume of the Companies’ derivative activity at September 30, 2026. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

		Dominion Energy								Virginia Power
		Current				Noncurrent				Current				Noncurrent
Natural Gas (bcf):
Fixed price(1)			25				—				23				—
Basis(1)			319				1,896				174				297
Electricity (MWh in millions):
Fixed price			9				34
FTRs			61								61
Interest rate(2) (in millions)		$	—			$	8,471			$	—			$	7,400
Foreign currency exchange rate(2) (in millions)
Danish Krone		229 kr.				—   kr.				229 kr.				—   kr.
Euro		€	98			€	—			€	98			€	—

(1)Includes options.

(2)Maturity is determined based on final settlement period.

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AOCI

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in the Companies’ Consolidated Balance Sheets at September 30, 2026:

		Dominion Energy										Virginia Power
		AOCI After-Tax				Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax				Maximum Term (months)		AOCI After-Tax				Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax				Maximum Term (months)
(millions)
Interest rate		$	(53	)		$	(21	)		399		$	61			$	1			399
Total		$	(53	)		$	(21	)				$	61			$	1

The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest rate payments) in earnings, thereby achieving the realization of prices contemplated by the underlying risk management strategies and will vary from the expected amounts presented above as a result of changes in interest rates.

Fair Value and Gains and Losses on Derivative Instruments

The following table presents the fair values of the Companies’ derivatives and where they are presented in their Consolidated Balance Sheets:

	Dominion Energy						Virginia Power
	Assets			Liabilities			Assets			Liabilities
(millions)
At September 30, 2026
Current derivatives not under cash flow hedge accounting
Commodity	$	219		$	168		$	41		$	34
Interest rate		—			—
Foreign currency exchange rate		2			9			2			9
Current derivatives under cash flow hedge accounting
Interest rate		—			—			—			—
Total current derivatives(1)	$	221		$	177		$	43		$	43
Noncurrent derivatives not under cash flow hedge accounting
Commodity	$	642		$	247		$	118		$	12
Interest rate		32			—
Foreign currency exchange rate		—			—			—			—
Noncurrent derivatives under cash flow hedge accounting
Interest rate		515			—			480			—
Total noncurrent derivatives(2)		1,189			247			598			12
Total derivatives	$	1,410		$	424		$	641		$	55
At December 31, 2025
Current derivatives not under cash flow hedge accounting
Commodity	$	295		$	98		$	172		$	12
Interest rate		—			3
Foreign currency exchange rate		25			10			25			10
Current derivatives under cash flow hedge accounting
Interest rate		15			—			15			—
Total current derivatives(1)	$	335		$	111		$	212		$	22
Noncurrent derivatives not under cash flow hedge accounting
Commodity	$	434		$	118		$	85		$	1
Interest rate		2			7
Foreign currency exchange rate		3			—			3			—
Noncurrent derivatives under cash flow hedge accounting
Interest rate		184			9			182			8
Total noncurrent derivatives(2)		623			134			270			9
Total derivatives	$	958		$	245		$	482		$	31

(1) The Companies’ current derivative liabilities are presented in other current liabilities in their Consolidated Balance Sheets.

(2) The Companies’ noncurrent derivative assets and liabilities are presented in other deferred charges and other assets and other deferred credits and other liabilities, respectively, in their Consolidated Balance Sheets.

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The following tables present the gains and losses on the Companies’ derivatives, as well as where the associated activity is presented in their Consolidated Balance Sheets and Statements of Income.

		Dominion Energy												Virginia Power
Derivatives in cash flow hedging relationships		Amount of Gain (Loss) Recognized in AOCI on Derivatives(1)				Amount of Gain (Loss) Reclassified from AOCI to Income				Increase (Decrease) in Derivatives Subject to Regulatory Treatment(2)				Amount of Gain (Loss) Recognized in AOCI on Derivatives(1)				Amount of Gain (Loss) Reclassified from AOCI to Income				Increase (Decrease) in Derivatives Subject to Regulatory Treatment(2)
(millions)
Three Months Ended September 30, 2026
Derivative type and location of gains (losses):
Interest rate(3)		$	75			$	(8	)		$	507			$	42			$	—			$	507
Total		$	75			$	(8	)		$	507			$	42			$	—			$	507
Three Months Ended September 30, 2025
Derivative type and location of gains (losses):
Interest rate(3)		$	(5	)		$	(10	)		$	(29	)		$	(2	)		$	—			$	(29	)
Total		$	(5	)		$	(10	)		$	(29	)		$	(2	)		$	—			$	(29	)
Nine Months Ended September 30, 2026
Derivative type and location of gains (losses):
Interest rate(3)		$	87			$	(25	)		$	495			$	40			$	1			$	494
Total		$	87			$	(25	)		$	495			$	40			$	1			$	494
Nine Months Ended September 30, 2025
Derivative type and location of gains (losses):
Interest rate(3)		$	(26	)		$	(30	)		$	(101	)		$	(9	)		$	—			$	(102	)
Total		$	(26	)		$	(30	)		$	(101	)		$	(9	)		$	—			$	(102	)

(1)Amounts deferred into AOCI have no associated effect in the Companies’ Consolidated Statements of Income.

(2)Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in the Companies’ Consolidated Statements of Income.

(3)Amounts recorded in the Companies’ Consolidated Statements of Income are classified in interest and related charges.

		Amount of Gain (Loss) Recognized in Income on Derivatives(1)(2)
Derivatives not designated as hedging instruments		Dominion Energy																Virginia Power
		Quarter-to-Date								Year-to-Date								Quarter-to-Date								Year-to-Date
Period Ended September 30,		2026				2025				2026				2025				2026				2025				2026				2025
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue		$	(23	)		$	(31	)		$	(226	)		$	(47	)		$	—			$	(8	)		$	—			$	(27	)
Purchased gas			(1	)			(1	)			1				(1	)
Purchased electric capacity			—				—				(7	)			—				—				—				(7	)			—
Electric fuel and other energy-related purchases			(60	)			102				215				207				(74	)			95				187				196
Interest rate:
Interest and related charges			43				1				91				(9	)
Total		$	(41	)		$	71			$	74			$	150			$	(74	)		$	87			$	180			$	169

(1)Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in the Companies’ Consolidated Statements of Income.

(2)Excludes amounts related to foreign currency exchange rate derivatives that are deferred to regulatory assets/liabilities that will begin to amortize as
the CVOW Commercial Project is placed in service.

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Note 9. Investments

Equity and Debt Securities

Rabbi Trust Securities

Equity and fixed income securities and cash equivalents in Dominion Energy’s rabbi trusts and classified as trading totaled $201 million and $181 million at September 30, 2026 and December 31, 2025, respectively.

Decommissioning Trust Securities

The Companies maintain nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants as summarized below:

		Dominion Energy																				Virginia Power
		Amortized Cost				Total Unrealized Gains				Total Unrealized Losses				Allowance for Credit Losses				Fair Value				Amortized Cost				Total Unrealized Gains				Total Unrealized Losses				Allowance for Credit Losses				Fair Value
(millions)
September 30, 2026
Equity securities:(1)
U.S.		$	1,087			$	5,840			$	(2	)						$	6,925			$	602			$	3,043			$	(2	)						$	3,643
International			41				143				—								184				26				74				—								100
Fixed income securities:(2)
Government    securities			328				—				(4	)		$	—				324				227				—				(2	)		$	—				225
Corporate debt    instruments			128				—				(4	)			—				124				128				—				(4	)			—				124
Private debt funds(3)			2,229				—				—				—				2,229				1,261				—				—				—				1,261
Insurance    contracts(4)			244				—				—				—				244
Cash equivalents    and other(5)			63				—				—				—				63				5				—				—				—				5
Total		$	4,120			$	5,983			$	(10	)	(6)	$	—			$	10,093			$	2,249			$	3,117			$	(8	)	(6)	$	—			$	5,358
December 31, 2025
Equity securities:(1)
U.S.		$	1,107			$	5,052			$	(2	)						$	6,157			$	602			$	2,620			$	(2	)						$	3,220
International			44				122				—								166				27				69				—								96
Fixed income securities:(2)
Government    securities			448				—				—			$	—				448				332				—				—			$	—				332
Private debt funds(3)			2,143				—				—				—				2,143				1,213				—				—				—				1,213
Insurance    contracts(4)			245				—				—				—				245				—				—				—				—				—
Cash equivalents    and other(5)			7				—				—				—				7				3				—				—				—				3
Total		$	3,994			$	5,174			$	(2	)	(6)	$	—			$	9,166			$	2,177			$	2,689			$	(2	)	(6)	$	—			$	4,864

(1)Unrealized gains and losses on equity securities are included in other income (expense) and the nuclear decommissioning trust regulatory liability.

(2)Unrealized gains and losses on fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability. Changes in allowance for credit losses are included in other income (expense).

(3)These private debt funds are generally structured without an explicit termination date. The Companies’ withdrawal and redemption rights begin after an initial multiyear lock-up period. Unless otherwise elected, distributions of income, profits and capital are generally reinvested in the underlying funds. The Companies may elect to receive a portion of future income as cash distributions, subject to fund liquidity restrictions. Generally, the Companies’ interests can be sold in the secondary markets subject to the approval of the general partner. Secondary markets tend to be less liquid especially during periods of market stress.

(4)Includes company owned life insurance contracts measured at cash surrender value.

(5)Dominion Energy includes pending sales of securities of $9 million and pending purchases of securities of $40 million at September 30, 2026 and December 31, 2025, respectively. Virginia Power includes pending sales of securities of $5 million and $3 million at September 30, 2026, and December 31, 2025, respectively.

(6)Dominion Energy’s fair value of securities in an unrealized loss position was $297 million and $48 million at September 30, 2026 and December 31, 2025, respectively. Virginia Power’s fair value of securities in an unrealized loss position was $227 million and $3 million at September 30, 2026 and December 31, 2025, respectively.

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The portion of unrealized gains and losses that relates to equity securities held within the Companies’ nuclear decommissioning trusts is summarized below:

	Dominion Energy
	Quarter-to-Date						Year-to-Date
Period Ended September 30,	2026			2025			2026			2025
(millions)
Net gains (losses) recognized during    the period	$	186		$	458		$	812		$	754
Less: Net (gains) losses recognized    during the period on securities    sold during the period		(9	)		(1	)		(4	)		15
Unrealized gains (losses) recognized    during the period on securities still    held at period end(1)	$	177		$	457		$	808		$	769

(1)Included in other income (expense) and the nuclear decommissioning trust regulatory liability.

	Virginia Power
	Quarter-to-Date						Year-to-Date
Period Ended September 30,	2026			2025			2026			2025
(millions)
Net gains (losses) recognized during    the period	$	84		$	236		$	430		$	389
Less: Net (gains) losses recognized    during the period on securities    sold during the period		(4	)		—			(3	)		11
Unrealized gains (losses) recognized    during the period on securities still    held at period end(1)	$	80		$	236		$	427		$	400

(1)Included in other income (expense) and the nuclear decommissioning trust regulatory liability.

The fair value of the Companies’ fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at September 30, 2026 by contractual maturity is as follows:

	Dominion Energy			Virginia Power
(millions)
Due in one year or less	$	2		$	—
Due after one year through five years		465			293
Due after five years through ten years		96			76
Due after ten years		199			157
Total	$	762		$	526

Presented below is selected information regarding the Companies’ equity and fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds.

	Dominion Energy
	Quarter-to-Date						Year to Date
Period Ended September 30,	2026			2025			2026			2025
(millions)
Proceeds from sales	$	531		$	869		$	2,839		$	2,563
Realized gains(1)		44			18			76			36
Realized losses(1)		39			15			81			57

(1)Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.

	Virginia Power
	Quarter-to-Date						Year to Date
Period Ended September 30,	2026			2025			2026			2025
(millions)
Proceeds from sales	$	396		$	489		$	1,979		$	1,412
Realized gains(1)		24			12			48			26
Realized losses(1)		23			11			51			40

(1)Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.

Equity Method Investments

There have been no significant changes to the equity method investments included in Note 9 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 except as described below.

Atlantic Coast Pipeline

A description of Dominion Energy’s investment in Atlantic Coast Pipeline, including events that led to the cancellation of the Atlantic Coast Pipeline Project in July 2020, is included in Note 9 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. Dominion Energy expects it could incur additional losses from Atlantic Coast Pipeline as it completes wind-down activities. While Dominion Energy is unable to precisely estimate the amounts to be incurred by Atlantic Coast Pipeline, the portion of such amounts attributable to Dominion Energy is not expected to be material to Dominion Energy’s results of operations, financial position or statement of cash flows. As a result of its share of equity losses exceeding its investment, Dominion Energy’s Consolidated Balance Sheets at September 30, 2026 and December 31, 2025 include a liability of $2 million and $4 million, respectively, presented in other current liabilities and reflecting Dominion Energy’s obligations to Atlantic Coast Pipeline related to AROs.

Dominion Privatization

At September 30, 2026 and December 31, 2025, Dominion Privatization had $8 million and $10 million of borrowings outstanding, respectively, related to its credit facility with Dominion Energy, reflected in other receivables in Dominion Energy’s Consolidated Balance Sheet.

Note 10. Property, Plant and Equipment

CVOW Commercial Project – Estimated Total Project Cost

As discussed in Note 10 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, Virginia Power is constructing the CVOW Commercial Project. Installation of the final turbines comprising the 2.6 GW project is expected to be completed by the end of 2027. The estimated total project cost is approximately $11.7 billion (excluding financing costs and including $0.1 billion of contingency) which continues to reflect revised network upgrade costs assigned by PJM to the CVOW Commercial Project, an estimated impact of certain

38

tariffs which became effective in April 2026 and updated turbine installation projections as well as previously included estimated impacts of a temporary suspension of work order, certain tariffs including those which became effective during 2025, the impact of the U.S. Supreme Court’s ruling in late February 2026 and tariffs which became effective in late February 2026. The Companies’ projected impact of tariffs on expected total project cost is subject to change due to the inherent uncertainty associated with which tariffs, if any, may be in effect and the associated requirements and rates of such tariffs.

The expected total project cost is unchanged from Virginia Power’s July 2026 construction update filing and reflects a decrease of approximately $0.4 billion, relative to Virginia Power’s January 2026 construction update filing, associated with a revision to projected onshore electrical interconnection costs and network upgrade costs allocated by PJM to the CVOW Commercial Project. The expected total project cost also reflects an increase of approximately $0.4 billion, relative to Virginia Power’s January 2026 construction update filing, $0.3 billion of which is associated with updated projections for turbine installations reflecting weather and other conditions with the remainder associated with other factors experienced, including increased fuel costs, during installations completed through July 2026. Relative to Virginia Power’s January 2026 construction update filing, the expected impact of tariffs on the expected total project cost is a net increase of approximately $0.1 billion as the increase of approximately $0.2 billion associated with revised Section 232 tariffs enacted in April 2026 on equipment expected to be delivered from April 2026 through the end of 2027 that contains steel, aluminum and/or copper products, including the associated impact such revised tariffs had on tariffs enacted in late February 2026 on equipment expected to be delivered from February 2026 through July 2026 that originates from Mexico, Canada, a European Union member or other applicable countries is partially offset by the reversal 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 in late February 2026, and the estimated impact of new tariffs subsequently enacted in late February 2026 on equipment expected to be delivered from February 2026 through July 2026 that originates from Mexico, Canada, a European Union member or other applicable countries. The actual tariffs to be incurred are dependent upon the tariff requirements and rates, if any, at the time of delivery of the specific component.

As a result of the current total project cost estimates and cost sharing mechanism, for the nine months ended September 30, 2026 Virginia Power recorded a net charge for costs not expected to be recovered from customers of $129 million within impairments of assets and other charges (benefits), which includes $64 million attributable to noncontrolling interests, and an associated income tax benefit of $17 million. No charge was recorded for the three months ended September 30, 2026. For the three and nine months ended September 30, 2025 Virginia Power recorded a charge for costs not expected to be recovered from customers of $128 million and $224 million, respectively, within impairment of assets and other charges (benefits), which includes $64 million and $112 million, respectively, attributable to noncontrolling interests, and an associated income tax benefit of $16 million and $28 million, respectively. All such amounts are reflected in the Corporate and Other segment in the Companies’ Consolidated Statements of Income. See Note 10 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 for more information on the cost sharing mechanism in the Virginia Commission’s December 2022 order and Stonepeak’s 50% noncontrolling interest in the CVOW Commercial Project.

The estimated total project cost above reflects the Companies’ best estimate of the remaining construction costs, including contingency of approximately 8% on such remaining amounts. Such estimate could potentially change for items, certain of which are beyond the Companies’ control, including but not limited to fuel for transportation and installation, the impact of applicable tariffs including any potential impact of Section 232 investigations, costs to maintain necessary permits, approvals and authorizations, any additional suspension of work orders, ability of key suppliers and contractors to timely satisfy their obligations under existing contracts, marine wildlife, actual network upgrade costs allocated by PJM, adverse weather and/or any severe weather events. Any additional increase in such costs in excess of the contingency included in the estimated total project cost would be subject to the cost sharing mechanisms discussed above and could have a material impact on the Companies’ future financial condition, results of operations and/or cash flows.

Nonregulated Solar Generation Facilities

In March 2026, Dominion Energy committed to a plan to sell certain nonregulated solar generation facilities within its Contracted Energy segment. As a result of meeting the requirements to be classified as held for sale, Dominion Energy recorded an impairment charge of $78 million ($60 million after-tax) in impairment of assets and other charges (benefits) in its Consolidated Statement of Income (reflected in the Corporate and Other segment) in the first quarter of 2026 to adjust the net assets associated with such facilities to their estimated fair value less cost to sell, using a market approach, of $500 million. In May 2026, Dominion Energy entered into an agreement with Enel to sell certain of these nonregulated solar generation facilities within its Contracted Energy segment for $140 million in cash, subject to customary closing adjustments. Subsequently, during the second quarter of 2026, Dominion Energy determined that it no longer had the intent to sell the remaining nonregulated solar generation facilities included in the March plan and reclassified their respective balances from held for sale to held and used at the lower of their original carrying amounts before the asset was classified as held for sale, adjusted for any depreciation expense not recognized while they were classified as held for sale, or their fair value. These balances primarily included

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property, plant and equipment, operating lease assets, deferred investment tax credits and operating lease liabilities. At September 30, 2026, the carrying amounts of major classes of assets remaining in held for sale are composed primarily of $262 million of net property, plant and equipment, as well as operating lease assets and a valuation allowance for assets held for sale with the carrying amount of major classes of liabilities remaining in held for sale composed primarily of deferred investment tax credits and operating lease liabilities. Following the satisfaction of all customary closing and regulatory conditions, including clearance or approval under the HSR and by FERC, the transaction closed in October 2026.

Nonregulated Renewable Natural Gas Facilities

In April 2026, Dominion Energy commenced an evaluation of its long-term intentions for its nonregulated renewable natural gas facilities within Contracted Energy. In connection with that evaluation, Dominion Energy expects that it is more likely than not that the nonregulated renewable natural gas facilities will be sold before the end of their useful lives and therefore evaluated the associated long-lived assets for recoverability during the second quarter of 2026. Using a probability-weighted approach, Dominion Energy determined Contracted Energy’s nonregulated renewable natural gas facilities were impaired and recorded a charge of $820 million ($640 million after-tax) in impairment of assets and other charges (benefits) in its Consolidated Statement of Income (reflected in the Corporate and Other segment) for the nine months ended September 30, 2026 to adjust the property, plant and equipment, net of associated deferred investment tax credits, down to its estimated fair value of $468 million. The fair value was estimated using an income approach. The valuation is considered a Level 3 fair value measurement due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risks inherent in the future cash flows and market prices.

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Note 11. Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	Dominion Energy							Virginia Power
	September 30, 2026			December 31, 2025				September 30, 2026			December 31, 2025
(millions)
Regulatory assets:
Deferred cost of fuel used in electric generation(1)	$	1,169		$	213			$	997		$	174
Securitized cost of fuel used in electric generation(2)		130			125				130			125
Riders OSW and CE(3)		62			23				62			23
Other deferred rider costs for Virginia electric utility(4)		151			445				151			445
Ash pond and landfill closure costs(5)		77			164				77			164
Deferred nuclear refueling outage costs(6)		99			101				99			101
NND Project costs(7)		138			138
Other		209			171				86			78
Regulatory assets-current		2,035			1,380				1,602			1,110
Unrecognized pension and other postretirement benefit costs(8)		503			527			—			—
Riders OSW and CE(3)		394			287				394			287
Other deferred rider costs for Virginia electric utility(4)		671			338				671			338
Interest rate hedges(9)		165			165				—		—
AROs and related funding(10)		409			385
NND Project costs(7)		1,569			1,672
CCR remediation, ash pond and landfill closure costs(5)		3,132			2,868				2,565			2,510
Deferred cost of fuel used in electric generation(1)		157			391				157			391
Securitized cost of fuel used in electric generation(2)		733			868				733			868
Other		798			775				149			132
Regulatory assets-noncurrent		8,531			8,276				4,669			4,526
Total regulatory assets	$	10,566		$	9,656			$	6,271		$	5,636
Regulatory liabilities:
Deferred cost of fuel used in electric generation(1)		3			3				3			3
Provision for future cost of removal and AROs(11)		101			101				101			101
Reserve for rate credits to electric utility customers(12)		21			34				—			—
Income taxes refundable through future rates(13)		121			110				77			77
Monetization of guarantee settlement(14)		67			67
Derivatives(15)		53			158				2			135
Other		103			69				101			58
Regulatory liabilities-current		469			542				284			374
Income taxes refundable through future rates(13)		2,735			2,854				1,963			2,046
Provision for future cost of removal and AROs(11)		1,987			1,950				1,370			1,346
Nuclear decommissioning trust(16)		2,801			2,494				2,801			2,494
Monetization of guarantee settlement(14)		451			501
Interest rate hedges(9)		954			461				954			461
Reserve for rate credits to electric utility customers(12)		121			128				—			—
Overrecovered other postretirement benefit costs(17)		230			209
Derivatives(15)		302			228				—			31
Other		396			247				301			152
Regulatory liabilities-noncurrent		9,977			9,072				7,389			6,530
Total regulatory liabilities	$	10,446		$	9,614			$	7,673		$	6,904

(1)Reflects deferred fuel expenses as well as, beginning in June 2025, deferred electric capacity expenses for the Virginia and North Carolina jurisdictions of Virginia Power’s electric generation operations. Additionally, Dominion Energy includes deferred fuel expenses for the South Carolina jurisdiction of its electric generation operations. In September 2026, the Virginia Commission issued an order permitting Virginia Power to securitize $932 million of under-recovered fuel costs for its Virginia service territory. See Note 12 for additional information.

(2)Reflects under-recovered fuel costs for Virginia Power’s Virginia service territory securitized through the issuance of bonds by VPFS in February 2024, which are being amortized into electric fuel and other energy-related purchases. See Note 18 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 for additional information.

(3)Deferred balances for Riders OSW and CE include amounts for shortfall or excess in energy sales, capacity revenue, renewable energy credits and production tax credits as such customer benefit amounts are included as a component, including an equity return, of the revenue requirements associated with each rate adjustment clause. In addition, the deferred Rider OSW balance at September 30, 2026 and December 31, 2025 includes $15 million and $4 million, respectively, for future decommissioning activities.

(4)Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects.

(5)Primarily reflects legislation in Virginia which requires any CCR asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through beneficial reuse. These deferred costs are expected to be collected over a period between 15 and 18 years commencing December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs on uncollected expenditures once expenditures have been made. In addition, the balance reflects amounts related to the EPA’s May 2024 final rule concerning CCR as discussed in Note 14 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

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(6)Primarily reflects deferred operation and maintenance costs at Virginia Power incurred in connection with the refueling of any nuclear-powered generating plant as required by Virginia legislation. Virginia Power deferred costs will be amortized over the refueling cycle, not to exceed 18 months.

(7)Reflects expenditures by DESC associated with the NND Project, which pursuant to the SCANA Merger Approval Order, will be recovered from DESC electric service customers over a 20-year period ending in 2039.

(8)Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered or refunded through future rates generally over the expected remaining service period of plan participants by certain of Dominion Energy’s rate-regulated subsidiaries.

(9)Reflects interest rate hedges recoverable from or refundable to customers. Certain of these instruments are settled and any related payments are being amortized into interest expense over the life of the related debt, which has a weighted-average useful life of approximately 24 years and 23 years for Dominion Energy and Virginia Power, respectively, at September 30, 2026.

(10)Represents uncollected costs, including deferred depreciation and accretion expense, related to legal obligations associated with the future retirement of generation, transmission and distribution properties. The AROs primarily relate to DESC’s electric generating facilities, including Summer, and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately 105 years.

(11)Rates charged to customers by Dominion Energy and Virginia Power’s regulated businesses include a provision for the cost of future activities to remove assets that are expected to be incurred at the time of retirement.

(12)Reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period effective February 2019, in connection with the SCANA Merger Approval Order.

(13)Amounts recorded to pass the effect of reduced income taxes from the 2017 Tax Reform Act to customers in future periods, which will primarily reverse at the weighted-average tax rate that was used to build the reserves over the remaining book life of the property, net of amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC equity.

(14)Reflects amounts to be refunded to DESC electric service customers over a 20-year period ending in 2039 associated with the monetization of a bankruptcy settlement agreement.

(15)Represents changes in the fair value of derivatives, excluding separately presented interest rate hedges, that following settlement are expected to be recovered from or refunded to customers.

(16)Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses, changes in fair value and taxes thereon, as applicable) for the future decommissioning of Virginia Power’s utility nuclear generation stations, in excess of the related AROs.

(17)Reflects a regulatory liability for the collection of postretirement benefit costs allowed in rates in excess of expense incurred.

At September 30, 2026, Dominion Energy and Virginia Power regulatory assets include $6.1 billion and $4.0 billion, respectively, on which they do not expect to earn a return during the applicable recovery period. With the exception of certain items discussed above, the majority of these expenditures are expected to be recovered within the next two years.

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Note 12. 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, 2025.

Virginia Regulation - Updates to Key Legislation Affecting Operations

Virginia 2020 Legislation

Renewable generation: In April 2026, the Governor of Virginia signed into law legislation which deems 16.0 GW of short-duration energy storage by the end of 2045, including 4.0 GW by the end of 2030, and 4.0 GW of long-duration energy storage by the end of 2045, including 2.0 GW by the end of 2035, which includes up to 800 MW for any one project which may include new or expanded pumped storage facilities, to be in the public interest.

Carbon trading program: In April 2026, the Governor of Virginia signed into law legislation that requires Virginia to establish and maintain a market-based carbon trading program consistent with RGGI, effective July 2026. All costs of the carbon trading program are recoverable through an environmental rider. In June 2026, the Governor of Virginia signed into law legislation that requires 45 percent of all revenue collected by Virginia pursuant to the market-based trading program be remitted to certain electric utilities, including Virginia Power, who will be subsequently required to distribute such funds to residential and certain commercial customers.

Virginia Regulation - Recent Developments

2025 Biennial Review

In November 2025, the Virginia Commission approved a base rate increase of $566 million effective January 2026 with an incremental base rate increase of $210 million effective January 2027. The Virginia Commission also authorized an ROE of 9.80% for Virginia Power that will be applied to Virginia Power’s riders prospectively and that will also be utilized to measure base rate earnings for the 2027 Biennial Review. See Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 for additional information. In March 2026, an appeal of the Virginia Commission’s order was filed with the Supreme Court of Virginia. This matter is pending.

Virginia Fuel Expenses

In May 2026, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $2.7 billion in Virginia jurisdictional projected fuel expense for the rate year beginning July 1, 2026 and a projected $1.1 billion under-recovered balance as of June 30, 2026. The projected under-recovered balance is comprised of $1.0 billion in projected and $66 million in actual under-recovered amounts from the rate years ended June 30, 2026 and 2025, respectively. Virginia Power proposed two alternatives to recover these under-collected fuel costs. The first option reflects recovery of the total $3.8 billion fuel cost requirement over the July 2026 through June 2027 fuel period and results in an increase in Virginia Power’s fuel revenues of $1.9 billion when applied to projected kilowatt-hour sales for the period. The second option proposed by Virginia Power incorporates its May 2026 application to the Virginia Commission for approval of a financing order to securitize up to the projected $1.0 billion under-recovered balance associated with the rate year ended June 30, 2026 as permitted under legislation enacted in Virginia in May 2026 authorizing Virginia Power to petition the Virginia Commission on or before July 2026 for approval of a financing order for certain deferred fuel costs. Under this option, Virginia Power proposed implementation of a rate to recover its projected current period fuel costs and the $66 million associated with under-recovered amounts from the rate year ended June 30, 2025 only effective July 2026 on an interim basis, while suspending implementation of the $1.0 billion associated with projected under-recovered amounts from the rate year ended June 30, 2026 pending the Virginia Commission’s consideration of the securitization petition. If approved by the Virginia Commission, the securitization option results in a net increase in Virginia Power’s fuel revenues for the rate year of approximately $702 million. In June 2026, the Virginia Commission ordered that, in accordance with Virginia Power’s second proposed option, the rate associated with the projected current period fuel costs and the $66 million associated with under-recovered amounts from the rate year ended June 30, 2025 be implemented effective July 2026 on an interim basis. In September 2026, the Virginia

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Commission issued an order finalizing these rates for the remainder of the fuel period. In May 2026, in accordance with legislation enacted in Virginia in May 2026 discussed above, Virginia Power filed an application with the Virginia Commission for approval of a financing order to securitize the projected $1.0 billion under-recovered fuel balance from the rate year ended June 30, 2026 through the issuance of one or more tranches of bonds with tenors up to approximately ten years, but no longer than approximately 15 years. In September 2026, the Virginia Commission issued an order permitting Virginia Power to securitize the under-recovered fuel balance of $932 million through the issuance of one or more tranches of bonds with tenors of no more than approximately seven years.

Virginia Power Equity Application

In March 2026, Virginia Power requested approval from the Virginia Commission to issue and sell to Dominion Energy up to $5.1 billion of authorized but unissued shares of its common stock, no par value, through the end of 2029 to maintain adequate credit metrics and efficient access to capital markets while funding necessary capital expenditures. In May 2026, the Virginia Commission granted Virginia Power approval to issue up to $3.6 billion of authorized but unissued shares of its common stock, through the end of 2029.

Renewable Generation Projects

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 845 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. In April 2026, the Virginia Commission approved CPCNs to construct or acquire and operate four utility-scale projects totaling approximately 532 MW of solar generation and one energy storage project totaling approximately 80 MW. The projects include Bedford and Pumpkinseed with the remaining projects approved in the April 2026 order expected to, as of October 2025, cost approximately $1.5 billion, excluding financing costs, and be placed into service between 2028 and 2029. Virginia Power is reviewing the order and assessing its options. In August 2026, two appeals of the Virginia Commission’s order were filed with the Supreme Court of Virginia. This matter is pending.

GTSA Filing

In March 2026, Virginia Power filed a petition with the Virginia Commission for approval of Phase IV, covering 2027 through 2029, of its plan for electric distribution grid transformation projects as authorized by the GTSA. The plan proposes to continue the mainfeeder hardening project on 41 additional feeders in 2027 through 2029, proposes the continued implementation of and investment in previously approved voltage island mitigation projects and voltage optimization enablement work and continued deployment of its previously approved telecommunications plan and select vegetation management programs. Virginia Power also requests approval for one new project, a stepdown conversion pilot program designed to proactively upgrade parts of the distribution system to a higher voltage, eliminating the need for 24 overhead 500 kVA and 333 kVA stepdown transformers. For Phase IV, the total proposed capital investment is $983 million and the proposed operations and maintenance investment is $125 million. In October 2026, the Virginia Commission issued an order approving portions of Virginia Power’s plan for Phase IV representing a total capital investment of $388 million and operations and maintenance investment of $125 million. Virginia Power may submit updated proposals with its Phase IVB application in 2027.

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, 2025.

Rider Name

Application Date

Approval Date

Rate Year Beginning

Total Revenue Requirement (millions)(1)

Increase (Decrease) from Previous (millions)

Rider CCR

April 2026

Pending

January 2027

$

217

$

51

Rider CE(2)

October 2025

April 2026

May 2026

280

98

Rider CERC

March 2026

Pending

January 2027

70

34

Rider DIST(3)

August 2025

May 2026

June 2026

327

60

Rider DIST(4)

August 2026

Pending

June 2027

463

136

Rider GEN

June 2026

Pending

April 2027

430

119

Rider GEN

June 2026

Pending

April 2028

408

(22

)

Rider OSW

October 2025

July 2026

September 2026

670

31

Rider OSW

October 2026

Pending

September 2027

627

(43

)

Rider RGGI(5)

June 2026

Pending

March 2027

1,179

N/A

Rider RPS

December 2025

August 2026

September 2026

442

(167

)

Rider SNA

October 2025

July 2026

September 2026

233

26

Rider SNA

October 2026

Pending

September 2027

281

48

Rider T1(6)

May 2026

July 2026

September 2026

1,539

196

DSM Riders(7)

December 2025

August 2026

September 2026

114

18

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(1)In addition, Virginia Power has riders associated with other projects with an aggregate total revenue requirement of approximately $65 million at September 30, 2026.

(2)As approved, associated with four solar generation projects, including Bedford and Pumpkinseed (non-jurisdictional generation facilities with an aggregate recorded cost of $251 million at September 30, 2025), one energy storage project, 10 purchased power agreements and certain costs associated with expanding solar and storage facilities in addition to previously approved Rider CE projects. Appeals have been filed with the Supreme Court of Virginia regarding this matter, which are currently pending.

(3)The total revenue requirement for Rider DIST includes $120 million for certain previously approved electric distribution grid transformation projects, $172 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. Virginia Power recognized a charge of $24 million ($18 million after-tax) recorded primarily in impairment of assets and other charges (benefits) in the Companies’ Consolidated Statements of Income (reflected in the Corporate and Other segment) for the nine months ended September 30, 2026, for the disallowance of certain strategic undergrounding costs previously incurred in connection with this final order. In addition, effective June 2026, the rider associated with rural broadband capacity projects was consolidated into Rider DIST and separate collection of rates under the rural broadband rider ceased.

(4)The total revenue requirement for Rider DIST includes $196 million for certain previously approved electric distribution grid transformation projects, $230 million for previously approved phases and proposed phase 10 of certain new underground distribution facilities and $37 million for certain previously approved rural broadband capacity projects.

(5)In June 2026, Virginia Power filed a petition to update and reinstate Rider RGGI to recover RGGI compliance costs incurred beginning July 2026 and those projected to occur through February 2028, with rate recovery from March 2027 through February 2028. In its petition, Virginia Power proposed an alternative mitigation approach which, if approved, would spread the recovery of costs over a two-year period and result in a total revenue requirement of $940 million for the rate year beginning March 2027.

(6)Consists of $599 million for the transmission component of Virginia Power’s base rates and $940 million for Rider T1.

(7)Associated with two redesigned energy efficiency programs and seven new demand response programs with a $221 million cost cap, with the ability to exceed the cost cap by no more than 15%. Also, in December 2025, Virginia Power filed a petition requesting Virginia Commission approval to conduct a pilot program to evaluate methods to optimize system demand through various technology applications and distributed energy resources, including the establishment of a VPP, as required by the Community Energy Act. In its petition, Virginia Power sought to utilize certain programs previously approved by the Virginia Commission and incorporate newly proposed programs associated with the DSM Riders. The DSM Riders cost cap includes $64 million associated with the proposed VPP pilot program. The Virginia Commission consolidated the DSM Riders and VPP pilot program petitions and approved all related matters in August 2026.

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, 2025.

Description and Location of Project

Application Date

Approval Date

Type of Line

Miles of Lines

Cost Estimate (millions)(1)

Construct new Culpeper Technology transmission lines, substations and related     projects in the Counties of Culpeper, Orange and Fauquier and the Town of     Culpeper, Virginia

February 2025

March 2026

230 kV

13

$

255

Construct new Golden-Mars transmission lines and related projects in Loudoun     County, Virginia

March 2025

June 2026

(2)

500- 230 kV

11

515

Partial rebuild Chesterfield-Lanexa transmission lines in the Counties of Henrico,     Charles City and New Kent, Virginia

September 2025

March 2026

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

August 2026

230 kV

22

125

Construct West Creek transmission line, substation and related projects     in the County of Goochland, Virginia

January 2026

September 2026

(3)

230 kV

7

100

Construct Morrisville-Wishing Star transmission lines and related projects in the     Counties of Fauquier, Prince William and Loudoun, Virginia

February 2026

Pending

500- 230 kV

45

875

Rebuild Charlottesville-Gordonsville transmission lines and related projects in the     County of Albermarle and the City of Charlottesville, Virginia

April 2026

Pending

230 kV

16

100

Construct Firehouse transmission lines, substation and related projects in the     County of Loudoun, Virginia

May 2026

Pending

230 kV

1

65

Construct Aspen-Doubs and Goose Creek-Woodside transmission lines,     rebuild Doubs-Goose Creek transmission line and related projects in the     County of Loudoun, Virginia

May 2026

Pending

500 kV

9

200

Construct new Allman Station switching station and related projects in the City      of Fredericksburg, Virginia

May 2026

Pending

230 kV

1

100

Install underbuilt transmission line on existing 500 kV Elmont-Ladysmith line      support structures and related projects in the Counties of Hanover and      Caroline, Virginia

June 2026

Pending

230 kV

26

60

(1)Represents the cost estimate included in the application except as updated in the approval if applicable. In addition, Virginia Power had one other transmission project applied for and currently pending approval with an aggregate cost estimate of approximately $20 million.

(2)In July 2026, appeals were filed with the Supreme Court of Virginia. This matter is pending.

(3)In October 2026, an appeal was filed with the Supreme Court of Virginia. This matter is pending.

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North Carolina Regulation - Recent Developments

Base Rate Case

In April 2026, Virginia Power filed its base rate case with the North Carolina Commission. Virginia Power proposed a non-fuel, base rate increase of $37 million effective December 1, 2026 on an interim basis subject to refund, with any permanent rates ordered by the North Carolina Commission effective March 1, 2027. The base rate increase was proposed to recover the significant investments in generation, transmission and distribution infrastructure for the benefit of North Carolina customers. Virginia Power presented an earned ROE of 7.53% based upon a fully-adjusted test period, compared to its authorized return of 9.95%, and proposed ROE of 10.50%. In addition, Virginia Power requested permission to establish a rider to recover certain costs associated with the CVOW Commercial Project. This matter is pending.

Fuel Filings

2025 Fuel Filing

In August 2026, Virginia Power’s revenue requirement for the fuel component of its electric rates increased by $23 million, to be collected over a 12-month period, consistent with its quarterly fuel status report filed with the North Carolina Commission in connection with Virginia Power’s fuel filing for the rate year beginning February 1, 2026, as approved by the North Carolina Commission in January 2026 as discussed in Note 13 to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

2026 Fuel Filing

In August 2026, Virginia Power submitted its annual filing to the North Carolina Commission to adjust the fuel component of its electric rates for the rate year beginning February 1, 2027. The first option proposed reflects a total $105 million increase to the fuel component of its electric rates, inclusive of $55 million in under-recovered fuel costs incurred during the 12-month period ended June 30, 2026. The second option proposed reflects a total $77 million increase to the fuel component of its electric rates for the rate year beginning February 1, 2027 by spreading the $55 million under-recovered fuel cost balance over a two-year period. Both options exclude amounts recovered through the adjustment made to Virginia Power’s revenue requirement for the fuel component of electric rates in North Carolina effective August 1, 2026 as discussed above. Virginia Power will have the opportunity to adjust fuel rates in a subsequent proceeding for any final true-up of this original deferral balance. This matter is pending.

South Carolina Regulation - Recent Developments

Electric Base Rate Case

In January 2026, DESC filed its retail electric base rate case and schedules with the South Carolina Commission. DESC proposed a non-fuel, base rate increase of $331 million, partially offset by a net decrease in storm damage and DSM components of $9 million. If approved, the overall proposed rate increase of $322 million, or 12.7%, would be effective on and after the first billing cycle of July 2026. The base rate increase was proposed to recover the continued investment in assets and operating resources required to serve DESC’s rapidly expanding customer base and evolving customer needs, while maintaining the safety, reliability, resiliency and efficiency of its system, and to meet increasingly stringent reliability, security and environmental requirements. DESC presented an ROE of 4.78% based upon a fully-adjusted test period. The proposed rates would provide for an earned ROE of 10.50% compared to the currently authorized ROE of 9.94%.

In May 2026, DESC, the South Carolina Office of Regulatory Staff and other parties of record filed a stipulation agreement with the South Carolina Commission for approval. The stipulation agreement provides for a non-fuel, base rate increase of $219 million prior to the effect of South Carolina Commission-ordered DSM reductions effective on and after the first billing cycle of July 2026 and an authorized ROE of 9.99%. In addition, the stipulation agreement includes that DESC will provide to residential customers a one-time refund and other customer assistance, resulting in after-tax charges of $5 million reflected in Dominion Energy’s Consolidated Statements of Income for both the three and six months ended June 30, 2026. In July 2026, the South Carolina Commission issued an order approving the stipulation agreement.

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 2026, 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 2026. In addition, DESC proposed to update its variable environmental and avoided capacity cost component. The net effect is a proposed annual increase of $36 million. In March 2026, DESC, the South Carolina Office of Regulatory Staff and another party filed a settlement agreement with the South Carolina Commission for approval to make certain adjustments to the February 2026 filing that would result in an inconsequential change to the proposed annual increase. In April 2026, the South Carolina Commission approved the settlement agreement, with rates effective with the first billing cycle of May 2026.

Electric DSM Programs

DESC has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In January 2026, DESC filed an application with the South Carolina Commission seeking approval to recover $54 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 2026. In April 2026, the South Carolina Commission approved the request, effective with the first billing cycle of May 2026.

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Canadys Station

In December 2025, DESC and Santee Cooper filed an application with the South Carolina Commission for approval of a CPCN to jointly construct and operate Canadys Station. Upon completion, DESC and Santee Cooper will each own a 50% undivided interest in the generating station and its electrical output. The application included an expected total cost of approximately $5 billion, excluding financing costs, with costs split equally between the joint owners for the proposed 2.2 GW facility. In addition, the application seeks approval for the construction of a new 230 kV switchyard and related transmission facilities which are expected to cost approximately $100 million, to be jointly owned by DESC and Santee Cooper, with costs split between the joint owners based on a formula reflecting shared use. In June 2026, the South Carolina Commission approved the request. The related facilities are expected to be placed into service in 2033. The estimated cost and project timelines are subject to refinement through the permitting process and the negotiation of contracts for major construction suppliers. In September 2026, two appeals were filed with the Supreme Court of South Carolina regarding this matter. This matter is pending.

Electric - Transmission Project

In July 2026, DESC filed an application with the South Carolina Commission requesting approval of a CPCN to reconductor five existing corridor lines currently connected to its Jasper substation in Jasper County, South Carolina, consisting of a total of 84 miles of 230 kV transmission lines with an estimated total project cost of approximately $110 million. In August 2026, the South Carolina Commission approved the request.

Natural Gas Rates

In June 2026, DESC filed with the South Carolina Commission its monitoring report for the 12-month period ended March 31, 2026 with a total revenue requirement of $676 million. This revenue requirement represents a $22 million base rate increase under the terms of the Natural Gas Rate Stabilization Act effective with the first billing cycle of November 2026. In October 2026, the South Carolina Commission approved a total revenue requirement of $675 million, representing a $21 million base rate increase after certain adjustments, effective for the first billing cycle of November 2026.

Note 13. Leases

Other than the items discussed below, there have been no significant changes regarding the Companies’ leases as described in Note 15 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

During the second quarter of 2026, Virginia Power recorded a right-of-use asset and offsetting lease obligation upon commencement of an operating lease for an energy storage facility with a term of approximately 15 years. At September 30, 2026, Virginia Power’s Consolidated Balance Sheet includes $269 million of other deferred charges and other assets for its right-of-use asset and $270 million of operating lease liabilities comprised of $9 million presented in other current liabilities and $261 million presented in other deferred credits and other liabilities related to this lease.

Dominion Energy’s Consolidated Statements of Income include $6 million and $15 million for the three and nine months ended September 30, 2026, respectively, and $6 million and $15 million for the three and nine months ended September 30, 2025, respectively, of rental revenue included in operating revenue. Dominion Energy’s Consolidated Statements of Income include $4 million and $11 million for the three and nine months ended September 30, 2026, respectively, and $4 million and $9 million for the three and nine months ended September 30, 2025, respectively, of depreciation expense included in depreciation and amortization related to facilities subject to power purchase agreements under which Dominion Energy is the lessor.

Note 14. Variable Interest Entities

There have been no significant changes regarding the entities the Companies consider VIEs as described in Note 16 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Virginia Power

Virginia Power purchased shared services from DES, an affiliated VIE, of $171 million and $145 million for the three months ended September 30, 2026 and 2025, respectively, and $522 million and $442 million for the nine months ended September 30, 2026 and 2025, respectively. Virginia Power’s Consolidated Balance Sheets include amounts due to DES of $58 million and $46 million at September 30, 2026 and December 31, 2025, respectively, recorded in payables to affiliates.

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As described in Note 18 of the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, Virginia Power formed VPFS in October 2023, a wholly-owned special purpose subsidiary which is considered to be a VIE, for the sole purpose of securitizing certain of Virginia Power’s under-recovered deferred fuel balance through the issuance of senior secured deferred fuel cost bonds. The Companies’ Consolidated Balance Sheets include balances for VPFS as follows:

		September 30, 2026				December 31, 2025
(millions)
Assets
Prepayments(1)		$	—			$	1
Regulatory assets-current			130				125
Other current assets(2)			104				51
Regulatory assets-noncurrent			733				868
Total assets		$	967			$	1,045
Liabilities
Securities due within one     year		$	176			$	171
Accrued interest, payroll     and taxes			20				9
Securitization bonds			794				883
Total liabilities		$	990			$	1,063

(1)Prepayments are presented in other current assets in Virginia Power’s Consolidated Balance Sheets.

(2)See Note 2 for additional information about restricted cash and equivalents at VPFS.

As described in Note 10 of the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, in October 2024 Virginia Power completed the sale of a 50% noncontrolling interest in the CVOW Commercial Project to Stonepeak through the sale of an interest in OSWP, which is considered to be a VIE. The Companies’ Consolidated Balance Sheets include balances for OSWP as follows:

		September 30, 2026				December 31, 2025
(millions)
Assets
Cash and cash equivalents		$	219			$	149
Other receivables			63				—
Regulatory assets-current			12				15
Other investments			3				—
Property, plant and     equipment			9,626				8,799
Accumulated depreciation     and amortization			(42	)			—
Regulatory assets-noncurrent			303				150
Other deferred charges and     other assets			30				9
Total assets		$	10,214			$	9,122
Liabilities
Accounts payable		$	3			$	2
Accrued interest, payroll     and taxes			5				2
Other current liabilities			26				16
Asset retirement obligations-     noncurrent(1)			446				220
Total liabilities		$	480			$	240

(1)Asset retirement obligations-noncurrent are presented in other deferred credits and other liabilities in the Companies’ Consolidated Balance Sheets.

Note 15. Significant Financing Transactions

Credit Facilities and Short-term Debt

The Companies use short-term debt to fund working capital requirements and as a bridge to long-term debt financings. The levels of borrowing may vary significantly during the course of the year, depending upon the timing and amount of cash requirements not satisfied by cash from operations. In addition, Dominion Energy utilizes cash and letters of credit to fund collateral requirements. Collateral requirements are impacted by capital projects, commodity prices, hedging levels, Dominion Energy’s credit ratings and the credit quality of its counterparties. Other than the items discussed below, there have been no significant changes regarding the Companies’ credit facilities and short-term debt as described in Note 17 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Dominion Energy

Dominion Energy’s short-term financing is primarily supported by its joint revolving credit facility.

At September 30, 2026, Dominion Energy’s commercial paper and letters of credit outstanding, as well as its capacity available under the credit facility discussed above and its supplemental revolving credit facility, were as follows:

	Facility Limit			Outstanding Commercial Paper			Outstanding Letters of Credit			Facility Capacity Available
(millions)
Joint revolving credit    facility(1)	$	7,000		$	2,939		$	4		$	4,057
Supplemental revolving   credit facility(2)		1,000			—						1,000
Total	$	8,000		$	2,939		$	4		$	5,057

(1)This credit facility matures in April 2031 in accordance with the extension exercised by the borrowers in April 2026, with the potential to be further extended by the borrowers to April 2032, and can be used by the borrowers under the credit facility to support bank borrowings and the issuance of commercial paper, as well as to support up to a combined $3.0 billion of letters of credit, for working capital and other general corporate purposes.

(2)This credit facility, entered into in April 2026 with certain lenders, matures in April 2028, with the potential to be extended by Dominion Energy to April 2029, contains a maximum allowed total debt to total capital ratio consistent with such allowed ratio under Dominion Energy’s joint revolving credit facility and can be used to support bank borrowings and the issuance of commercial paper.

In addition to the credit facilities mentioned above, Dominion Energy’s credit facilities and agreements also consist of the following:

•An agreement entered into with a financial institution in March 2023, which it expects to allow it to issue up to $100 million in letters of credit. At September 30, 2026 and December 31, 2025, $27 million and $26 million in letters of credit were issued and outstanding under this agreement, respectively.

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•An agreement entered into with a financial institution in June 2024, subsequently amended in January 2025, which it expects to allow it to issue up to a combined $275 million in letters of credit at either Dominion Energy or Virginia Power. At September 30, 2026 and December 31, 2025, Dominion Energy had $100 million and $102 million in letters of credit issued and outstanding under this agreement, including $79 million and $81 million for Virginia Power, respectively.

•An agreement entered into with a financial institution in January 2025, most recently amended in July 2026, which it expects to allow it to issue up to a combined $450 million in letters of credit, with $50 million available exclusively to Dominion Energy and $400 million available exclusively to Virginia Power. At September 30, 2026 and December 31, 2025, Dominion Energy had $380 million and $150 million in letters of credit issued and outstanding under this agreement, including $330 million and $100 million for Virginia Power, respectively. Through October 2026, Dominion Energy had $367 million in letters of credit issued and outstanding under this agreement, including $317 million for Virginia Power.

•An agreement entered into with a financial institution in
September 2025, subsequently amended in December 2025, which it expects to allow it to issue up to $500 million in letters of credit with $100 million available exclusively to Dominion Energy and $400 million available exclusively to Virginia Power. At September 30, 2026 and December 31, 2025, Dominion Energy had $351 million and $379 million, respectively, in letters of credit issued and outstanding under this agreement, all of which was issued and outstanding for Virginia Power.

Dominion Energy has an effective shelf registration statement with the SEC for the sale of up to $3.0 billion of variable denomination floating rate demand notes, called Dominion Energy Reliability InvestmentSM as disclosed in Note 17 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. At September 30, 2026 and December 31, 2025, Dominion Energy’s Consolidated Balance Sheets include $369 million and $422 million, respectively, with respect to such notes presented within short-term debt. The proceeds are used for general corporate purposes and to repay debt.

In February 2026, Dominion Energy entered into an approximately $1.3 billion 364-day term loan facility as described in Note 17 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. Prior to the termination of the facility in August 2026, Dominion Energy borrowed and repaid the full capacity of the facility with the proceeds used to repay existing debt and for general corporate purposes.

Virginia Power

Virginia Power’s short-term financing is supported through its access as co-borrower to Dominion Energy’s $7.0 billion joint revolving credit facility.

At September 30, 2026, Virginia Power’s share of commercial paper and letters of credit outstanding under the joint revolving credit facility with Dominion Energy and DESC was as follows:

	Facility Limit			Outstanding Commercial Paper			Outstanding Letters of Credit
(millions)
Joint revolving credit    facility(1)	$	7,000		$	485		$	1

(1)The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy and DESC. The sub-limit for Virginia Power is set pursuant to the terms of the facility but can be changed at the option of the borrowers multiple times per year. At September 30, 2026, the sub-limit for Virginia Power was $4.0 billion. If Virginia Power has liquidity needs in excess of its current sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term intercompany borrowings from Dominion Energy. This credit facility matures in April 2031 in accordance with the extension exercised by the borrowers in April 2026, with the potential to be further extended by the borrowers to April 2032, and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $3.0 billion (or the sub-limit, whichever is less) of letters of credit, for working capital and other general corporate purposes.

In addition to the credit facility mentioned above, Virginia Power’s credit facilities and agreements also consist of the following:

•An agreement entered into with a financial institution in March 2023, subsequently amended in June 2026, which it expects to allow it to issue up to $450 million in letters of credit. At September 30, 2026 and December 31, 2025, $278 million and $281 million, respectively, in letters of credit were issued and outstanding under this agreement. In October 2026, this agreement was amended under which Virginia Power expects to allow it to issue up to $500 million in letters of credit.

•An agreement entered into with a financial institution in June 2024, subsequently amended in January 2025, which it expects to allow it to issue up to a combined $275 million in letters of credit at either Dominion Energy or Virginia Power. At September 30, 2026 and December 31, 2025, Virginia Power had $79 million and $81 million, out of Dominion Energy’s total $100 million and $102 million, respectively, in letters of credit issued and outstanding under this agreement.

•An agreement entered into with a financial institution in January 2025, most recently amended in July 2026, which it expects to allow Dominion Energy to issue up to a combined $450 million in letters of credit, with $50 million available exclusively to Dominion Energy and $400 million available exclusively to Virginia Power. At September 30, 2026 and December 31, 2025, Virginia Power had $330 million and $100 million, respectively, in letters of credit issued and outstanding under this agreement. Through October 2026, Virginia Power had $317 million in letters of credit issued and outstanding under this agreement.

•An agreement entered into with a financial institution in September 2025, subsequently amended in December

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2025, which it expects to allow Dominion Energy to issue up to $500 million in letters of credit with $100 million available exclusively to Dominion Energy and $400 million available exclusively to Virginia Power. At September 30, 2026 and December 31, 2025, Virginia Power had $351 million and $379 million, respectively, in letters of credit issued and outstanding under this agreement.

•Agreements entered into with financial institutions in September 2025, which it expects to allow it to issue up to $2.0 billion in letters of credit. At September 30, 2026 and December 31, 2025, Virginia Power had $980 million and $1.0 billion, respectively, in letters of credit issued and outstanding under these agreements.

•An agreement entered into with a financial institution in July 2026, which it expects to allow it to issue up to $250 million in letters of credit. At September 30, 2026, Virginia Power had no letters of credit issued and outstanding under this agreement.

Long-term Debt

Unless otherwise noted, the proceeds of long-term debt issuances were used for general corporate purposes and/or to repay short-term debt.

In February 2026, Dominion Energy borrowed $500 million under the Sustainability Revolving Credit Agreement as described in Note 18 to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, with the proceeds used to support environmental sustainability and social investment initiatives, which was repaid in March 2026. In May 2026, Dominion Energy borrowed $500 million under this agreement with the proceeds used to support environmental sustainability and social investment initiatives. Dominion Energy repaid $300 million in June 2026 and $200 million in July 2026. At both September 30, 2026 and December 31, 2025, Dominion Energy had no borrowings outstanding under this facility. In April 2026, the facility was amended to, among other things, extend the maturity date from April 2028 to April 2029, with the potential to be further extended by Dominion Energy to April 2031. There were no changes to the key financial covenants.

In March 2026, Virginia Power issued $1.3 billion of 4.95% senior notes and $850 million of 5.70% senior notes that mature in 2036 and 2056, respectively.

In June 2026, Dominion Energy issued $825 million of 5.35% senior notes that mature in 2036.

In June 2026, Dominion Energy issued $1.5 billion of junior subordinated notes, consisting of $1.0 billion of 2026 Series A JSNs and $500 million of 2026 Series B JSNs that both mature in 2056. The 2026 Series A JSNs will bear interest at 6.150% until December 15, 2031. The interest rate will reset every five years beginning December 15, 2031 to equal the then-current five-year U.S. Treasury rate plus a spread of 1.869%, provided that the interest rate will not reset below 6.150%. The 2026 Series B JSNs will bear interest at 6.250% until December 15, 2036. The interest rate will be reset every five years beginning on December 15, 2036 to equal the then-current five-year U.S. Treasury rate plus a spread of 1.702%, provided that the interest rate will not reset below 6.250%. Dominion Energy may defer interest payment on the 2026 Series A JSNs or 2026 Series B JSNs on one or more occasions for up to 10 consecutive years. If interest payments on the 2026 Series A JSNs or the 2026 Series B JSNs are deferred, Dominion Energy may not, subject to certain limited exceptions, declare or pay any dividends or other distributions on, or redeem, repurchase or otherwise acquire any of its capital stock during the deferral period. Also, during the deferral period, Dominion Energy may not make any payments on or redeem or repurchase any debt securities or make any payments under any guarantee of debt that, in each case, is equal or junior in right of payment to the 2026 Series A JSNs and the 2026 Series B JSNs.

In August 2026, Virginia Power issued $1.3 billion of 5.65% senior notes that mature in 2036 and $700 million of 6.30% senior notes that mature in 2056.

In September 2026, DESC issued $300 million of 6.15% first mortgage bonds that mature in 2056.

In October 2026, DESC renewed letters of credit securing industrial revenue bonds totaling $68 million. These letters of credit are subject to renewal in the fourth quarter of 2027.

Preferred Stock

Dominion Energy is authorized to issue up to 20 million shares of preferred stock, which may be designated into separate classes. At both September 30, 2026 and December 31, 2025, Dominion Energy had issued and outstanding 1.0 million shares of the Series C Preferred Stock.

Dominion Energy recorded dividends on the Series C Preferred Stock of $11 million ($10.875 per share) for both the three months ended September 30, 2026 and 2025 and $33 million ($32.625 per share) for both the nine months ended September 30, 2026 and 2025, respectively. There have been no significant changes to Dominion Energy’s Series C Preferred Stock as described in Note 19 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Issuance of Common Stock

Dominion Energy recorded, net of fees and commissions, $40 million from the issuance of one million shares of common stock for the nine months ended September 30, 2026 and $105 million from the issuance of two million shares of common stock for the nine months ended September 30, 2025, through various programs, including Dominion Energy Direct® and employee savings plans as described in Note 20 to the Consolidated Financial Statements to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. In May 2026, Dominion Energy began purchasing its common stock on the open market for these direct stock purchase plans.

In June 2026, Virginia Power issued 6,046 shares of its common stock to Dominion Energy for $450 million with the proceeds utilized to reduce the aggregate amount outstanding

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under its intercompany credit facility with Dominion Energy. Virginia Power issued the shares pursuant to a Virginia Commission order authorizing the issuance of up to $3.6 billion of common stock through the end of 2029 in order to maintain adequate credit metrics and efficient access to capital markets while funding necessary capital expenditures, as discussed in Note 13.

In June 2025, Virginia Power issued 30,006 shares of its common stock to Dominion Energy for $2.1 billion and in August 2025, issued 19,630 shares of its common stock to Dominion Energy for $1.4 billion. The proceeds for both issuances were utilized to reduce the aggregate amount outstanding under its intercompany credit facility with Dominion Energy. Virginia Power issued the shares pursuant to a Virginia Commission order discussed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

At-the-Market Programs

May 2024 At-the-Market Program

In May 2024, Dominion Energy entered into sales agency agreements to effect sales under an existing at-the-market program. During the third quarter of 2025, Dominion Energy entered into forward sale agreements for approximately 2.4 million shares of its common stock expected to be settled by the fourth quarter of 2027 at a weighted-average initial forward price of $59.91 per share. Except in certain circumstances, Dominion Energy can elect physical, cash or net settlement of the forward sale agreements. There have been no significant changes regarding this at-the-market program as described in Note 20 to the Consolidated Financial Statements to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

February 2025 At-the-Market Program

In February 2025, Dominion Energy entered into sales agency agreements to effect sales under a new at-the-market program as described in Note 20 to the Consolidated Financial Statements to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. During the second quarter of 2025, Dominion Energy entered into forward sale agreements for approximately 11.0 million shares of its common stock expected to be settled in the fourth quarter of 2026 at a weighted-average initial forward price of $55.83 per share. During the third quarter of 2025, Dominion Energy entered into forward sale agreements for approximately 9.6 million shares of its common stock expected to be settled by the fourth quarter of 2027 at a weighted-average initial forward price of $61.11 per share. In December 2025, Dominion Energy provided notice to elect physical settlement of approximately 5.4 million shares under these forward sales agreements, and in December 2025 settled the agreements at a weighted-average final forward price of $60.44 per share.

In October 2025, Dominion Energy increased the maximum amount of capacity available under this at-the-market program by $1.8 billion.

During the first quarter of 2026, Dominion Energy entered into forward sale agreements for approximately 3.2 million shares of its common stock expected to be settled by the fourth quarter of 2027 at a weighted-average initial forward price of $62.96 per share. During the second quarter of 2026, Dominion Energy entered into forward sale agreements for approximately 7.9 million shares of its common stock expected to be settled by the fourth quarter of 2026 at a weighted-average initial forward price of $67.88 per share. Except in certain circumstances, Dominion Energy can elect physical, cash or net settlement of the forward sale agreements.

Repurchase of Common Stock

In November 2020, the Board of Directors authorized the repurchase of up to $1.0 billion of Dominion Energy’s common stock, with $0.9 billion available at September 30, 2026.

Dominion Energy did not repurchase any shares of common stock during the nine months ended September 30, 2026, except for shares tendered by employees to satisfy tax withholding obligations on vested restricted stock, which do not count against its stock repurchase authorization.

Dividend Restrictions

As discussed in Note 1, Dominion Energy may be required to obtain the consent of NextEra Energy related to the payment of dividends in excess of $0.6675 per share each quarter. There have been no other significant changes to dividend restrictions affecting the Companies described in Note 21 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Note 16. Commitments and Contingencies

As a result of issues generated in the ordinary course of business, the Companies are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such 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 litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations 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. The Companies maintain various insurance programs, including general liability

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insurance coverage which provides coverage for personal injury or wrongful death cases. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent the Companies’ maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on the Companies’ financial position, liquidity or results of operations.

Environmental Matters

The Companies are subject to costs resulting from a number of federal, state and local laws and regulations designed to protect human health and the environment. These laws and regulations affect future planning and existing operations. They can result in increased capital, operating and other costs as a result of compliance, remediation, containment and monitoring obligations.

Air

The CAA, as amended, is a comprehensive program utilizing a broad range of regulatory tools to protect and preserve the nation’s air quality. At a minimum, state-established regulatory programs are required to meet applicable requirements of the CAA. However, states may choose to develop regulatory programs that are more restrictive. Many of the Companies’ facilities are subject to the CAA’s permitting and other requirements.

Ozone Standards

The EPA published final non-attainment designations for the October 2015 ozone standards in June 2018 with states required to develop plans to address the new standard. Certain states in which the Companies operate have developed plans, and had such plans approved or partially approved by the EPA, which are not expected to have a material impact on the Companies’ results of operations or cash flows. In March 2023, the EPA issued a final rule specifying an interstate federal implementation plan to comply with certain aspects of planning for the 2015 ozone standards which was applicable in August 2023 for certain states, including Virginia. The interstate federal implementation plan imposes tighter NOX emissions limits during the ozone season and includes provisions for the use of allowances to cover such emissions. Unless and until implementation plans for the 2015 ozone standards are fully developed and approved and in effect for all states in which the Companies operate, the Companies are unable to predict whether or to what extent the new rules will ultimately require additional controls. The expenditures required to implement additional controls could have a material impact on the Companies’ results of operations, financial condition and/or cash flows.

Carbon Regulations

In August 2016, the EPA issued a draft rule proposing to reaffirm that a source’s obligation to obtain a PSD or Title V permit for GHGs is triggered only if such permitting requirements are first triggered by non-GHG, or conventional, pollutants that are regulated by the New Source Review program, and exceed a significant emissions rate of 75,000 tons per year of CO2 equivalent emissions. Until the EPA ultimately takes final action on this rulemaking, the Companies cannot predict the impact to their results of operations, financial condition and/or cash flows.

Water

The CWA, as amended, is a comprehensive program requiring a broad range of regulatory tools including a permit program to authorize and regulate discharges to surface waters with strong enforcement mechanisms. The Companies must comply with applicable aspects of the CWA programs at their operating facilities.

Regulation 316(b)

In October 2014, the final regulations under Section 316(b) of the CWA that govern existing facilities and new units at existing facilities that employ a cooling water intake structure and that have flow levels exceeding a minimum threshold became effective. The rule establishes a national standard for impingement based on seven compliance options, but forgoes the creation of a single technology standard for entrainment. Instead, the EPA has delegated entrainment technology decisions to state regulators. State regulators are to make case-by-case entrainment technology determinations after an examination of five mandatory facility-specific factors, including a social cost-benefit test, and six optional facility-specific factors. The rule governs all electric generating stations with water withdrawals above two MGD, with a heightened entrainment analysis for those facilities over 125 MGD. Dominion Energy and Virginia Power currently have 14 and eight facilities, respectively, that are subject to the final regulations. Dominion Energy is also working with the EPA and state regulatory agencies to assess the applicability of Section 316(b) to eight hydroelectric facilities, including three Virginia Power facilities. The Companies anticipate that they may have to install impingement control technologies at certain of these stations that have once-through cooling systems. The Companies are currently evaluating the need or potential for entrainment controls under the final rule as these decisions will be made on a case-by-case basis after a thorough review of detailed biological, technological and cost benefit studies. DESC is conducting studies and implementing plans as required by the rule to determine appropriate intake structure modifications at certain facilities to ensure compliance with this rule. While the impacts of this rule could be material to the Companies’ results of operations, financial condition and/or cash flows, the existing regulatory frameworks in South Carolina and Virginia provide rate recovery mechanisms that could substantially mitigate any such impacts for the regulated electric utilities.

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Effluent Limitations Guidelines

In September 2015, the EPA released a final rule to revise the Effluent Limitations Guidelines for the Steam Electric Power Generating Category. The final rule established updated standards for wastewater discharges that apply primarily at coal and oil steam generating stations. Affected facilities are required to convert from wet to dry or closed cycle coal ash management, improve existing wastewater treatment systems and/or install new wastewater treatment technologies in order to meet the new discharge limits. In April 2017, the EPA granted two separate petitions for reconsideration of the Effluent Limitations Guidelines final rule and stayed future compliance dates in the rule. Also in April 2017, the U.S. Court of Appeals for the Fifth Circuit granted the EPA’s request for a stay of the pending consolidated litigation challenging the rule while the EPA addresses the petitions for reconsideration. In September 2017, the EPA signed a rule to postpone the earliest compliance dates for certain waste streams regulations in the Effluent Limitations Guidelines final rule from November 2018 to November 2020; however, the latest date for compliance for these regulations was December 2023. In October 2020, the EPA released the final rule that extended the latest dates for compliance with individual facilities’ compliance dates that would vary based on circumstances and the determination by state regulators and may range from 2021 to 2028. In May 2024, the EPA released a final rule revising the 2015 and 2020 Effluent Limitations Guidelines, establishing more stringent standards for wastewater discharges for the Steam Electric Power Generating Category, which apply primarily to wastewater discharges at coal and oil steam generating stations. In December 2025, the EPA released a final rule that among other things, extended the deadlines promulgated in the May 2024 final rule. Individual facilities’ compliance dates will vary based on circumstances and the determination by state regulators and may range from 2029 to 2034. Dominion Energy expects to complete wastewater treatment technology retrofits and modifications at its Williams generating station, with a similar project at its Wateree generation station under evaluation, to meet the requirements with the existing regulatory framework in South Carolina providing rate recovery mechanisms for costs of the projects. As discussed in Note 14 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, the Companies recorded an increase to their AROs in connection with the expected compliance costs associated with the EPA’s May 2024 final rule concerning CCR. The Companies expect that such AROs would satisfy any AROs that would have otherwise been necessary for compliance with the EPA’s May 2024 Effluent Limitations Guidelines, as amended by the December 2025 final rule. Dominion Energy is currently unable to estimate what costs, if any, may be required in addition to the project for the Williams generating station, a potential project at the Wateree generating station and the recorded AROs to meet the requirements to operate certain facilities past 2034. However, Dominion Energy expects that while such costs for facility improvements, if required, could be material to the Companies’ financial condition and/or cash flows, the existing regulatory frameworks in Virginia and South Carolina provide rate recovery mechanisms that could substantially mitigate any such impacts.

Waste Management and Remediation

The operations of the Companies are subject to a variety of state and federal laws and regulations governing the management and disposal of solid and hazardous waste, and release of hazardous substances associated with current and/or historical operations. The CERCLA, as amended, and similar state laws, may impose joint, several and strict liability for cleanup on potentially responsible parties who owned, operated or arranged for disposal at facilities affected by a release of hazardous substances. In addition, many states have created programs to incentivize voluntary remediation of sites where historical releases of hazardous substances are identified and property owners or responsible parties decide to initiate cleanups.

From time to time, the Companies may be identified as a potentially responsible party in connection with the alleged release of hazardous substances or wastes at a site. Under applicable federal and state laws, the Companies could be responsible for costs associated with the investigation or remediation of impacted sites, or subject to contribution claims by other responsible parties for their costs incurred at such sites. The Companies also may identify, evaluate and remediate other potentially impacted sites under voluntary state programs. Remediation costs may be subject to reimbursement under the Companies’ insurance policies, rate recovery mechanisms, or both. Except as described below, the Companies do not believe these matters will have a material effect on results of operations, financial condition and/or cash flows.

Dominion Energy has determined that it is associated with former manufactured gas plant sites, including certain sites associated with Virginia Power. At four sites associated with Dominion Energy, remediation work has been substantially completed under federal or state oversight. Where required, the sites are following state-approved groundwater monitoring programs. Dominion Energy has proposed remediation plans for one site at Virginia Power and expects to commence remediation activities in 2027 depending on receipt of final permits and approvals. At both September 30, 2026 and December 31, 2025, Dominion Energy had $53 million of reserves recorded including $48 million recorded at Virginia Power. Dominion Energy is associated with three additional sites, including two associated with Virginia Power, which are not under investigation by any state or federal environmental agency nor the subject of any current or proposed plans to perform remediation activities. Due to the uncertainty surrounding such sites, the Companies are unable to make an estimate of the potential financial statement impacts.

Other Legal Matters

The Companies are defendants in a number of lawsuits and claims involving unrelated incidents of property damage and personal injury. Due to the uncertainty surrounding these matters, the Companies are unable to make an estimate of the

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potential financial statement impacts; however, they could have a material impact on results of operations, financial condition and/or cash flows.

Guarantees, Surety Bonds and Letters of Credit

Dominion Energy enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion Energy would be obligated to satisfy such obligation. To the extent that a liability subject to a guarantee has been incurred by one of Dominion Energy’s consolidated subsidiaries, that liability is included in the Consolidated Financial Statements. Dominion Energy is not required to recognize liabilities for guarantees issued on behalf of its subsidiaries unless it becomes probable that it will have to perform under the guarantees. Terms of the guarantees typically end once obligations have been paid. Dominion Energy currently believes it is unlikely that it would be required to perform or otherwise incur any losses associated with guarantees of its subsidiaries’ obligations. At September 30, 2026, Dominion Energy had issued the following subsidiary guarantees:

		Maximum Exposure
(millions)
Commodity transactions(1)		$	3,165
Nuclear obligations(2)			170
Solar(3)			85
Other(4)			371
Total(5)(6)(7)		$	3,791

(1)Guarantees related to commodity commitments of certain subsidiaries. These guarantees were provided to counterparties in order to facilitate physical and financial transaction related commodities and services.

(2)Guarantees primarily related to certain DGI subsidiaries regarding all aspects of running a nuclear facility.

(3)Includes guarantees to facilitate the development of solar projects.

(4)Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations, construction projects and insurance programs. Due to the uncertainty of workers’ compensation claims, the parental guarantee has no stated limit.

(5)Excludes Dominion Energy’s performance guarantees with no stated limits associated with Dominion Privatization’s agreements to provide utility services to the U.S. government on military installations.

(6)In December 2020, Dominion Energy signed an agreement with a lessor to complete construction of and lease a Jones Act compliant offshore wind installation vessel. In September 2025, the vessel was delivered and the five-year lease term commenced. At the end of the initial lease term, Dominion Energy can (i) extend the term of the lease for an additional term, subject to the approval of the participants, at current market terms, (ii) purchase the property for an amount equal to the outstanding project costs or (iii) subject to certain terms and conditions, sell the property on behalf of the lessor to a third party using commercially reasonable efforts to obtain the highest cash purchase price for the property. If the project is sold and the proceeds from the sale are insufficient to repay the investors for the outstanding project costs, Dominion Energy may be required to make a payment to the lessor equal to the recorded lease balance.

(7)In July 2016, Dominion Energy signed an agreement with a lessor to construct and lease a new corporate office property in Richmond, Virginia and commenced an initial five-year lease term in August 2019, with certain options at the end of the term to extend the lease, purchase or sell the property. In July 2024, the agreement was amended to reflect Dominion Energy’s election to extend the lease term through July 2029. At the end of the lease term, Dominion Energy can (i) extend the term of the lease for at least one year, subject to the approval of the participants, at current market terms, (ii) purchase the property for an amount equal to the project costs or (iii) subject to certain terms and conditions, sell the property on behalf of the lessor to a third party using commercially reasonable efforts to obtain the highest cash purchase price for the property. If the project is sold and the proceeds from the sale are insufficient to repay the investors for the project costs, Dominion Energy may be required to make a payment to the lessor equal to the recorded lease balance.

In addition, Dominion Energy had issued an additional $20 million of guarantees at September 30, 2026, primarily to support third parties. No amounts related to these guarantees have been recorded.

Dominion Energy has entered into two guarantee agreements to support a portion of Valley Link’s financing obligations under a $530 million revolving credit facility, as amended in October 2026, and up to $120 million of letters of credit. Dominion Energy’s obligation under these guarantees is only triggered if a Valley Link project is cancelled and Valley Link cannot pay outstanding balances related to the cancelled project. Dominion Energy’s maximum potential loss exposure under the terms of the guarantees is limited to 30% of outstanding borrowings, an equal percentage to Dominion Energy’s ownership in Valley Link. At September 30, 2026 and December 31, 2025, Valley Link had borrowed $107 million and $41 million, respectively, against the revolving credit facility and had $90 million outstanding letters of credit at both dates. No amounts related to these guarantees has been recorded at Dominion Energy.

Dominion Energy also had issued three guarantees at September 30, 2026 related to Cove Point, previously an equity method investment, in support of terminal services and transportation. Two of the Cove Point guarantees have a cumulative maximum exposure of $1.9 billion while the other one guarantee has no maximum limit. No amounts related to these guarantees have been recorded.

Additionally, at September 30, 2026, Dominion Energy had purchased $579 million of surety bonds, including $490 million at Virginia Power, and authorized the issuance of letters of credit by financial institutions, as discussed in Note 15, to facilitate commercial transactions by its subsidiaries with third parties. Under the terms of surety bonds, the Companies are obligated to indemnify the respective surety bond company for any amounts paid.

Note 17. Credit Risk

The Companies’ accounting policies for credit risk are discussed in Note 24 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. Virginia Power’s largest customer comprised 10% and 9% of its operating revenue for the three months ended September 30, 2026 and 2025, respectively, and

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12% and 9% of its operating revenue for the nine months ended September 30, 2026 and 2025, respectively, and 6% and 10% of its customer receivables at September 30, 2026 and December 31, 2025, respectively.

At September 30, 2026, Dominion Energy’s credit exposure totaled $786 million, primarily related to price risk management activities. Of this amount, investment grade counterparties, including those internally rated, represented 99%. No single counterparty, whether investment grade or non-investment grade, exceeded $443 million of exposure. At September 30, 2026, Virginia Power’s exposure related to wholesale customers totaled $39 million. Of this amount, investment grade counterparties, including those internally rated, represented 90%. No single counterparty, whether investment grade or non-investment grade, exceeded $18 million of exposure.

Credit-Related Contingent Provisions

Certain of Dominion Energy and Virginia Power’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion Energy and Virginia Power to provide collateral upon the occurrence of specific events, primarily a credit rating downgrade. If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered, Dominion Energy would have been required to post additional collateral to its counterparties of $33 million at September 30, 2026 with none related to Virginia Power, and $29 million at December 31, 2025 for Dominion Energy with none related to Virginia Power. The collateral that would be required to be posted includes the impacts of any offsetting asset positions and any amounts already posted for derivatives, non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. Dominion Energy and Virginia Power had no amounts of collateral posted at September 30, 2026 or December 31, 2025 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. There were no letters of credit posted as collateral at September 30, 2026 or December 31, 2025 for either Dominion Energy or Virginia Power. The aggregate fair value of all derivative instruments with credit related contingent provisions that are in a liability position and not fully collateralized with cash for Dominion Energy was $33 million at September 30, 2026 with none related to Virginia Power, and $29 million at December 31, 2025 for Dominion Energy with none related to Virginia Power, which does not include the impact of any offsetting asset positions.

See Note 8 for additional information about derivative instruments.

Note 18. Related-Party Transactions

Dominion Energy’s transactions with equity method investments are described in Note 9. Virginia Power engages in related-party transactions primarily with other Dominion Energy subsidiaries (affiliates). Virginia Power’s receivable and payable balances with affiliates are settled based on contractual terms or on a monthly basis, depending on the nature of the underlying transactions. Virginia Power is included in Dominion Energy’s consolidated federal income tax return and, where applicable, combined income tax returns for Dominion Energy are filed in various states. A discussion of Virginia Power’s significant related-party transactions follows.

Virginia Power transacts with affiliates for certain quantities of natural gas and other commodities in the ordinary course of business. Virginia Power also enters into certain commodity derivative contracts with affiliates. Virginia Power uses these contracts, which are principally comprised of forward commodity purchases, to manage commodity price risks associated with purchases of natural gas. At September 30, 2026, Virginia Power’s derivative assets and liabilities with affiliates were $9 million and $13 million, respectively. At December 31, 2025, Virginia Power’s derivative assets and liabilities with affiliates were $22 million and $12 million, respectively. See Note 8 for additional information.

Virginia Power participates in certain Dominion Energy benefit plans described in Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. At September 30, 2026 and December 31, 2025, amounts due to Dominion Energy associated with the Dominion Energy Pension Plan and included in other deferred credits and other liabilities in the Consolidated Balance Sheets were $691 million and $594 million, respectively. At September 30, 2026 and December 31, 2025, Virginia Power’s amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan and included in other deferred charges and other assets in the Consolidated Balance Sheets were $776 million and $729 million, respectively.

DES and other affiliates provide accounting, legal, finance and certain administrative and technical services to Virginia Power. In addition, Virginia Power provides certain services to affiliates, including charges for facilities and equipment usage.

The financial statements for all years presented include costs for certain general, administrative and corporate expenses assigned by DES to Virginia Power on the basis of direct and allocated methods in accordance with Virginia Power’s services agreements with DES. Where costs incurred cannot be determined by specific identification, the costs are allocated based on the proportional level of effort devoted by DES resources that is attributable to the entity, determined by reference to number of employees, salaries and wages and other similar measures for the relevant DES service. Management believes the assumptions and methodologies

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underlying the allocation of general corporate overhead expenses are reasonable.

Presented below are Virginia Power’s significant transactions with DES and other affiliates:

		Quarter-to-Date								Year-to-Date
Period Ended September 30,		2026				2025				2026				2025
(millions)
Commodity purchases from     affiliates		$	170			$	221			$	983			$	734
Services provided by     affiliates(1)(2)			239				203				718				608
Services provided to affiliates			4				4				13				11

(1)Includes capitalized expenditures of $92 million and $76 million for the three months ended September 30, 2026 and 2025, respectively, and $270 million and $222 million for the nine months ended September 30, 2026 and 2025, respectively.

(2)Excludes amounts related to Virginia Power's operating lease with an affiliated entity as discussed below.

Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were $403 million and $1.2 billion in short-term demand note borrowings from Dominion Energy at September 30, 2026 and December 31, 2025, respectively. Virginia Power had no outstanding borrowings, net of repayments, under the Dominion Energy money pool for its nonregulated subsidiaries at both September 30, 2026 and December 31, 2025. Interest charges related to Virginia Power’s borrowings from Dominion Energy were $11 million and $4 million for the three months ended September 30, 2026 and 2025, respectively, and $36 million and $40 million for the nine months ended September 30, 2026 and 2025, respectively.

In the second quarter of 2026 and the second and third quarters of 2025, Virginia Power issued common stock to Dominion Energy as discussed in Note 15.

In September 2025, Virginia Power commenced a 20-month operating lease with an affiliated entity for the use of a Jones Act compliant offshore wind installation vessel. At September 30, 2026, Virginia Power’s Consolidated Balance Sheet reflects Virginia Power’s expected use of the vessel through the end of 2027 and includes $177 million of other deferred charges and other assets for its right-of-use asset and $178 million of affiliated lease payables comprised of $141 million presented in other current liabilities and $37 million presented in other deferred credits and other liabilities. At December 31, 2025, Virginia Power’s Consolidated Balance Sheet reflects $185 million of other deferred charges and other assets for its right-of-use asset and $188 million of affiliated lease payables comprised of $141 million presented in other current liabilities and $47 million presented in other deferred credits and other liabilities. For the three and nine months ended September 30, 2026, Virginia Power capitalized $28 million and $100 million, respectively, of such affiliated lease cost associated with the CVOW Commercial Project. For both the three and nine months ended September 30, 2025, Virginia Power capitalized $11 million of such affiliated lease cost associated with the CVOW Commercial Project.

Note 19. Employee Benefit Plans

Net Periodic Benefit (Credit) Cost

The service cost component of net periodic benefit (credit) cost is reflected in other operations and maintenance expense in Dominion Energy’s Consolidated Statements of Income. The non-service cost components of net periodic benefit (credit) cost are reflected in other income (expense) in Dominion Energy’s Consolidated Statements of Income. The components of Dominion Energy’s provision for net periodic benefit (credit) cost are as follows:

		Pension Benefits																Other Postretirement Benefits
		Quarter-to-Date								Year-to-Date								Quarter-to-Date								Year-to-Date
Period Ended September 30,		2026				2025				2026				2025				2026				2025				2026				2025
(millions)
Service cost		$	19			$	19			$	57			$	57			$	2			$	3			$	7			$	8
Interest cost			108				108				323				325				13				13				40				42
Expected return on plan assets			(159	)			(170	)			(476	)			(508	)			(43	)			(39	)			(130	)			(119	)
Amortization of prior service (credit) cost			—				1				1				1				(5	)			(6	)			(16	)			(19	)
Net periodic benefit (credit) cost		$	(32	)		$	(42	)		$	(95	)		$	(125	)		$	(33	)		$	(29	)		$	(99	)		$	(88	)

Employer Contributions

During the three and nine months ended September 30, 2026, Dominion Energy made $8 million and $18 million, respectively, of contributions to its qualified defined benefit pension plans. Dominion Energy expects to make $18 million of minimum required contributions to its qualified defined benefit pension plans in 2026. Dominion Energy is not required to make any contributions to its VEBAs associated with its other postretirement plans in 2026. Dominion Energy considers voluntary contributions from time to time, either in the form of cash or equity securities.

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Note 20. Operating Segments

The Companies are organized primarily on the basis of products and services sold in the U.S. A description of the operations included in the Companies’ primary operating segments is as follows:

Primary Operating Segment		Description of Operations		Dominion Energy		Virginia Power
Dominion Energy    Virginia		Regulated electric distribution		X		X
		Regulated electric transmission		X		X
		Regulated electric generation    fleet(1)		X		X
Dominion Energy    South Carolina		Regulated electric distribution		X
		Regulated electric transmission		X
		Regulated electric generation    fleet		X
		Regulated gas distribution    and storage		X
Contracted Energy(2)		Nonregulated electric    generation fleet		X

(1)Includes Virginia Power’s non-jurisdictional solar generation operations.

(2)Includes renewable natural gas and offshore wind installation vessel operations.

In addition to the operating segments above, the Companies also report a Corporate and Other segment.

Dominion Energy

The Corporate and Other Segment of Dominion Energy includes its corporate, service company and other functions (including unallocated debt) as well as its noncontrolling interest in Dominion Privatization. In addition, Corporate and Other includes specific items attributable to Dominion Energy’s operating segments that are not included in profit measures evaluated by executive management in assessing the segments’ performance or in allocating resources, including the net impact of the operations reflected as discontinued operations, which includes a noncontrolling interest in Atlantic Coast Pipeline, as discussed in Note 9 of this report as well as Note 9 to the Consolidated Financial Statements in Dominion Energy’s Annual Report on Form 10-K for the year ended December 31, 2025.

Dominion Energy’s CODM is the CEO. The Dominion Energy CODM uses net income (loss) as the primary profit or loss measure at each segment. The Dominion Energy CODM considers budget-to-actual variances on a quarterly basis when making decisions about allocating operating and capital resources to each segment, when assessing the performance of each segment and when determining the compensation of certain employees.

In the nine months ended September 30, 2026, Dominion Energy reported after-tax net expenses of $826 million in the Corporate and Other segment, including $577 million of after-tax net expenses for specific items with $572 million of after-tax net expenses attributable to its operating segments. In the nine months ended September 30, 2025, Dominion Energy reported after-tax net expenses of $108 million in the Corporate and Other segment, including $58 million of after-tax net income for specific items with $81 million of after-tax net income attributable to its operating segments.

The net expenses for specific items attributable to Dominion Energy’s operating segments in 2026 primarily related to the impact of the following items:

•A $820 million ($640 million after-tax) charge for the impairment of nonregulated renewable natural gas facilities, attributable to Contracted Energy;

•$172 million ($129 million after-tax) of net unrealized losses related to economic hedging activities, attributable to Contracted Energy;

•A $119 million ($88 million after-tax) loss associated with severe weather events, attributable to Dominion Energy Virginia;

•A $79 million ($61 million after-tax) charge associated with certain nonregulated solar generation facilities, attributable to Contracted Energy;

•$65 million ($48 million after-tax) net charges for Virginia Power’s share of costs not expected to be recovered from customers on the CVOW Commercial Project, attributable to Dominion Energy Virginia;

•A $24 million ($18 million after-tax) charge for the disallowance of certain strategic undergrounding costs, attributable to Dominion Energy Virginia; and

•A $14 million ($11 million after-tax) charge for the termination of certain supply contracts associated with renewable natural gas operations, attributable to Contracted Energy; partially offset by

•$438 million ($293 million after-tax) of gains related to investments in nuclear decommissioning trust funds, attributable to:

•Contracted Energy ($256 million after-tax); and

•Dominion Energy Virginia ($37 million after-tax); and

•A $195 million ($142 million after-tax) benefit related to the revision of AROs for Millstone Unit 1, attributable to Contracted Energy.

The net income for specific items attributable to Dominion Energy’s operating segments in 2025 primarily related to the impact of the following items:

•A $415 million ($255 million after-tax) gain related to investments in nuclear decommissioning trust funds, attributable to:

•Contracted Energy ($221 million after-tax); and

•Dominion Energy Virginia ($34 million after-tax); partially offset by

•A $112 million ($84 million after-tax) charge for Virginia Power’s share of costs not expected to be recovered from customers on the CVOW Commercial Project, attributable to Dominion Energy Virginia;

•A $106 million ($79 million after-tax) loss associated with severe weather events, attributable to Dominion Energy Virginia; and

•A $16 million ($12 million after-tax) net unrealized loss related to economic hedging activities, attributable to Contracted Energy.

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The following tables present segment information pertaining to Dominion Energy’s operations:

Three Months Ended September 30,	Dominion Energy Virginia				Dominion Energy South Carolina				Contracted Energy				Corporate and Other				Adjustments & Eliminations				Consolidated Total
(millions, unless otherwise noted)
2026
Total revenue from external customers	$	4,214			$	1,111			$	302			$	(10	)		$	—			$	5,617
Intersegment revenue		4				3				35				345				(387	)			—
Total Operating Revenue		4,218				1,114				337				335				(387	)			5,617
Electric fuel and other energy-related purchases(1)		1,296				277				34				—				(4	)			1,603
Purchased electric capacity(1)		103				5				—				—				(2	)			106
Purchased gas(1)		—				35				5				—				—				40
Other operations and maintenance(1)(2)		744				183				153				374				(365	)			1,089
Depreciation and amortization(1)		509				163				40				22				(12	)			722
Other taxes(1)		104				83				16				15				(3	)			215
Total Operating Expenses		2,756				746				248				411				(386	)			3,775
Interest and related charges(1)		312				76				24				259				(48	)			623
Income tax expense (benefit)(1)		232				65				(41	)			(41	)			—				215
Equity in earnings (losses) of equity method investees(3)		—				—				—				2				—				2
Other income (expense)(3)		48				—				(3	)			184				—				229
Interest income(3)		10				3				31				43				(47	)			40
Net Income (Loss) From Discontinued Operations    Including Noncontrolling Interests		—				—				—				(1	)			—				(1	)
Noncontrolling Interests(3)		114				—				—				—				—				114
Net Income (Loss) Attributable to    Dominion Energy		862				230				134				(66	)			—				1,160
Investment in equity method investees(4)		—				—				87				36				—				123
Total assets (billions)		88.2				20.5				11.1				10.0				(5.0	)			124.8
2025
Total revenue from external customers	$	3,313			$	942			$	290			$	(18	)		$	—			$	4,527
Intersegment revenue		(2	)			3				7				299				(307	)			—
Total Operating Revenue		3,311				945				297				281				(307	)			4,527
Electric fuel and other energy-related purchases(1)		1,071				239				31				—				(4	)			1,337
Purchased electric capacity(1)		32				5				—				—				(1	)			36
Purchased gas(1)		—				30				1				—				—				31
Other operations and maintenance(1)(2)		581				168				103				428				(300	)			980
Depreciation and amortization(1)		415				141				30				23				—				609
Other taxes(1)		92				77				15				13				(2	)			195
Total Operating Expenses		2,191				660				180				464				(307	)			3,188
Interest and related charges(1)		236				69				15				250				(43	)			527
Income tax expense (benefit)(1)		169				53				(33	)			27				—				216
Equity in earnings (losses) of equity method investees(3)		—				—				1				(1	)			—				—
Other income (expense)(3)		45				—				7				354				—				406
Interest income(3)		5				5				22				37				(43	)			26
Net Income (Loss) From Discontinued Operations    Including Noncontrolling Interests		—				—				—				—				—				—
Noncontrolling Interests(3)		86				—				—				(64	)			—				22
Net Income (Loss) Attributable to    Dominion Energy		679				168				165				(6	)			—				1,006

(1)The significant expense categories and amounts in the segment information presented above align with the segment-level information that is regularly provided to Dominion Energy’s CODM.

(2)Includes impairment of assets and other charges (benefits).

(3)Items designated are other segment items for each reportable segment.

(4)Excludes liability to Atlantic Coast Pipeline.

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Nine Months Ended September 30,	Dominion Energy Virginia				Dominion Energy South Carolina				Contracted Energy				Corporate and Other				Adjustments & Eliminations				Consolidated Total
(millions, unless otherwise noted)
2026
Total revenue from external customers	$	11,392			$	2,976			$	903			$	(155	)		$	—			$	15,116
Intersegment revenue		12				8				119				1,047				(1,186	)			—
Total Operating Revenue		11,404				2,984				1,022				892				(1,186	)			15,116
Electric fuel and other energy-related purchases(1)		3,732				700				96				7				(11	)			4,524
Purchased electric capacity(1)		246				12				—				—				(3	)			255
Purchased gas(1)		—				223				13				—				—				236
Other operations and maintenance(1)(2)		2,001				530				515				1,972				(1,101	)			3,917
Depreciation and amortization(1)		1,347				465				128				64				(36	)			1,968
Other taxes(1)		309				251				49				54				(10	)			653
Total Operating Expenses		7,635				2,181				801				2,097				(1,161	)			11,553
Interest and related charges(1)		832				221				76				763				(153	)			1,739
Income tax expense (benefit)(1)		562				129				(55	)			(251	)			—				385
Equity in earnings (losses) of equity method investees(3)		—				—				—				2				—				2
Other income (expense)(3)		138				(1	)			(9	)			694				18				840
Interest income(3)		20				9				93				134				(146	)			110
Net Income (Loss) From Discontinued Operations    Including Noncontrolling Interests		—				—				—				(3	)			—				(3	)
Noncontrolling Interests(3)		331				—				—				(64	)			—				267
Net Income (Loss) Attributable to    Dominion Energy		2,202				461				284				(826	)			—				2,121
Investment in equity method investees(4)		—				—				87				36				—				123
Capital expenditures		7,163				984				435				74				(63	)			8,593
Total assets (billions)		88.2				20.5				11.1				10.0				(5.0	)			124.8
2025
Total revenue from external customers	$	8,818			$	2,724			$	834			$	37			$	—			$	12,413
Intersegment revenue		(1	)			8				15				901				(923	)			—
Total Operating Revenue		8,817				2,732				849				938				(923	)			12,413
Electric fuel and other energy-related purchases(1)		2,569				605				81				—				(10	)			3,245
Purchased electric capacity(1)		56				9				—				—				(2	)			63
Purchased gas(1)		—				220				1				—				—				221
Other operations and maintenance(1)(2)		1,671				516				378				1,195				(903	)			2,857
Depreciation and amortization(1)		1,208				423				74				66				—				1,771
Other taxes(1)		281				231				45				49				(8	)			598
Total Operating Expenses		5,785				2,004				579				1,310				(923	)			8,755
Interest and related charges(1)		733				210				31				694				(155	)			1,513
Income tax expense (benefit)(1)		412				100				7				(43	)			—				476
Equity in earnings (losses) of equity method investees(3)		—				—				—				(8	)			—				(8	)
Other income (expense)(3)		119				—				(1	)			674				—				792
Interest income(3)		17				11				90				137				(155	)			100
Net Income (Loss) From Discontinued Operations    Including Noncontrolling Interests		—				—				—				—				—				—
Noncontrolling Interests(3)		234				—				—				(112	)			—				122
Net Income (Loss) Attributable to    Dominion Energy		1,789				429				321				(108	)			—				2,431
Capital expenditures		7,695				832				682				56				2				9,267

(1)The significant expense categories and amounts in the segment information presented above align with the segment-level information that is regularly provided to Dominion Energy’s CODM.

(2)Includes impairment of assets and other charges (benefits).

(3)Items designated are other segment items for each reportable segment.

(4)Excludes liability to Atlantic Coast Pipeline.

Intersegment sales and transfers for Dominion Energy are based on contractual arrangements and may result in intersegment profit or loss that is eliminated in consolidation, including amounts related to entities presented within discontinued operations.

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Virginia Power

The Corporate and Other Segment of Virginia Power primarily includes specific items attributable to its operating segment that are not included in profit measures evaluated by executive management in assessing the segment’s performance or in allocating resources.

Virginia Power’s CODM is the CEO. The Virginia Power CODM uses net income (loss) as the primary profit or loss measure at each segment. The Virginia Power CODM considers budget-to-actual variances on a quarterly basis when making decisions about allocating operating and capital resources to each segment, when assessing the performance of each segment and when determining the compensation of certain employees.

In the nine months ended September 30, 2026, Virginia Power reported after-tax net expenses of $102 million in the Corporate and Other segment, including $126 million of after-tax net expenses for specific items all of which was attributable to its operating segment. In the nine months ended September 30, 2025, Virginia Power reported after-tax net expenses of $101 million in the Corporate and Other segment, including $127 million of after-tax net expenses for specific items all of which was attributable to its operating segment.

The net expenses for specific items attributable to Virginia Power’s operating segment in 2026 primarily related to the impact of the following items:

•A $119 million ($88 million after-tax) loss associated with severe weather events;

•$65 million ($48 million after-tax) net charges for Virginia Power’s share of costs not expected to be recovered from customers on the CVOW Commercial Project; and

•A $24 million ($18 million after-tax) charge for the disallowance of certain strategic undergrounding costs; partially offset by

•$63 million ($37 million after-tax) of gains related to investments in nuclear decommissioning trust funds.

The net expenses for specific items attributable to Virginia Power’s operating segment in 2025 primarily related to the impact of the following items:

•A $112 million ($84 million after-tax) charge for Virginia Power’s share of costs not expected to be recovered from customers on the CVOW Commercial Project; and

•A $106 million ($79 million after-tax) loss associated with severe weather events; partially offset by

•A $59 million ($34 million after-tax) gain related to investments in nuclear decommissioning trust funds.

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The following tables present segment information pertaining to Virginia Power’s operations:

Three Months Ended September 30,		Dominion Energy Virginia				Corporate and Other				Consolidated Total
(millions, unless otherwise noted)
2026
Operating Revenue		$	4,218			$	—			$	4,218
Electric fuel and other energy-related purchases(1)			1,296				—				1,296
Purchased electric capacity(1)			103				—				103
Other operations and maintenance(1)(2)			745				2				747
Depreciation and amortization(1)			509				—				509
Other taxes(1)			104				—				104
Total Operating Expenses			2,757				2				2,759
Interest and related charges(1)			311				1				312
Income tax expense (benefit)(1)			232				(12	)			220
Other income (expense)(3)			48				9				57
Interest income(3)			10				—				10
Noncontrolling Interests(3)			114				—				114
Net Income Attributable to Virginia Power			862				18				880
Total assets (billions)			86.8				—				86.8
2025
Operating Revenue		$	3,311			$	—			$	3,311
Electric fuel and other energy-related purchases(1)			1,071				—				1,071
Purchased electric capacity(1)			32				—				32
Other operations and maintenance(1)(2)			581				125				706
Depreciation and amortization(1)			415				3				418
Other taxes(1)			92				1				93
Total Operating Expenses			2,191				129				2,320
Interest and related charges(1)			236				(1	)			235
Income tax expense (benefit)(1)			169				(18	)			151
Other income (expense)(3)			45				34				79
Interest income(3)			5				1				6
Noncontrolling Interests(3)			86				(64	)			22
Net Income (Loss) Attributable to Virginia Power			679				(11	)			668

(1)The significant expense categories and amounts in the segment information presented above align with the segment-level information that is regularly provided to Virginia Power’s CODM.

(2)Includes impairment of assets and other charges (benefits).

(3)Items designated are other segment items for each reportable segment.

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Nine Months Ended September 30,		Dominion Energy Virginia				Corporate and Other				Consolidated Total
(millions, unless otherwise noted)
2026
Operating Revenue		$	11,405			$	(70	)		$	11,335
Electric fuel and other energy-related purchases(1)			3,732				7				3,739
Purchased electric capacity(1)			246				—				246
Other operations and maintenance(1)(2)			2,002				194				2,196
Depreciation and amortization(1)			1,347				—				1,347
Other taxes(1)			309				—				309
Total Operating Expenses			7,636				201				7,837
Interest and related charges(1)			832				1				833
Income tax expense (benefit)(1)			562				(43	)			519
Other income (expense)(3)			138				63				201
Interest income(3)			20				—				20
Noncontrolling Interests(3)			331				(64	)			267
Net Income (Loss) Attributable to Virginia Power			2,202				(102	)			2,100
Capital expenditures			7,162				—				7,162
Total assets (billions)			86.8				—				86.8
2025
Operating Revenue		$	8,817			$	(29	)		$	8,788
Electric fuel and other energy-related purchases(1)			2,569				—				2,569
Purchased electric capacity(1)			56				—				56
Other operations and maintenance(1)(2)			1,671				294				1,965
Depreciation and amortization(1)			1,208				4				1,212
Other taxes(1)			281				1				282
Total Operating Expenses			5,785				299				6,084
Interest and related charges(1)			733				(4	)			729
Income tax expense (benefit)(1)			412				(56	)			356
Other income (expense)(3)			119				54				173
Interest income(3)			17				1				18
Noncontrolling Interests(3)			234				(112	)			122
Net Income (Loss) Attributable to Virginia Power			1,789				(101	)			1,688
Capital expenditures			7,690				—				7,690

(1)The significant expense categories and amounts in the segment information presented above align with the segment-level information that is regularly provided to Virginia Power’s CODM.

(2)Includes impairment of assets and other charges (benefits).

(3)Items designated are other segment items for each reportable segment.

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ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

MD&A discusses Dominion Energy’s results of operations, general financial condition and liquidity and Virginia Power’s results of operations. MD&A should be read in conjunction with the Companies’ Consolidated Financial Statements. Virginia Power meets the conditions to file under the reduced disclosure format, and therefore has omitted certain sections of MD&A.

Contents of MD&A

MD&A consists of the following information:

•Forward-Looking Statements—Dominion Energy and Virginia Power

•Accounting Matters—Dominion Energy

•Results of Operations—Dominion Energy and Virginia Power

•Segment Results of Operations—Dominion Energy

•Outlook—Dominion Energy

•Liquidity and Capital Resources—Dominion Energy

•Future Issues and Other Matters—Dominion Energy

Forward-Looking Statements

This report contains statements concerning the Companies’ expectations, plans, objectives, future financial performance and other statements that are not historical facts. These statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. In most cases, the reader can identify these forward-looking statements by such words as “path”, “anticipate”, “believe”, “forecast”, “could”, “estimate”, “expect”, “intend”, “may”, “plan”, “outlook”, “predict”, “project”, “should”, “strategy”, “continue”, “target”, “will”, “potential” or other similar words.

The Companies make forward-looking statements with full knowledge that risks and uncertainties exist that may cause actual results to differ materially from predicted results. Factors that may cause actual results to differ are often presented with the forward-looking statements themselves. Additionally, other factors may cause actual results to differ materially from those indicated in any forward-looking statement. These factors include but are not limited to:

•Risks and uncertainties that may impact the ability of the parties to complete the proposed NextEra Energy Merger at all, or within the anticipated terms and time frames, including the ability to obtain applicable regulatory approvals and any associated terms and conditions of such approvals and any other events or changes in circumstances that could give rise to the termination of the NextEra Energy Merger Agreement by either party;

•The impacts of the proposed NextEra Energy Merger, including certain covenants in the NextEra Energy Merger Agreement, and any related uncertainties and disruptions on the Companies’ business, including on the Companies’ ability to hire and retain employees and/or on the Companies’ relationships with regulators and other governmental agencies, customers, suppliers, vendors and/or other third parties;

•Unusual weather conditions and their effect on energy sales to customers and energy commodity prices;

•Extreme weather events and other natural disasters, including, but not limited to, hurricanes, high winds, severe storms, earthquakes, flooding, wildfires, climate changes and changes in water temperatures and availability that can cause outages and property damage to facilities;

•The impact of extraordinary external events, such as the pandemic health event resulting from COVID-19, and their collateral consequences, including extended disruption of economic activity in the Companies’ markets and global supply chains;

•Federal, state and local legislative and regulatory developments;

•Changes in or interpretations of federal and state tax laws and regulations, including those related to tax credits or other incentives;

•Risks of operating businesses in regulated industries that are subject to changing regulatory structures;

•Changes to regulated electric rates collected by the Companies and regulated gas distribution rates collected by Dominion Energy;

•Changes in rules for RTOs and ISOs in which the Companies join and/or participate, including changes in rate designs, changes in FERC’s interpretation of market rules and new and evolving capacity models;

•Risks associated with Virginia Power’s membership and participation in PJM, including risks related to obligations created by the default of other participants;

•Risks associated with entities in which the Companies share ownership with third parties, such as Stonepeak’s noncontrolling interest in the CVOW Commercial Project, including risks that result from lack of sole decision-making authority, disputes that may arise between the Companies and third-party participants and difficulties in exiting these arrangements;

•Timing and receipt of regulatory approvals necessary for planned construction or growth projects and compliance with conditions associated with such regulatory approvals;

•The inability to complete planned construction, conversion or growth projects at all, or with the outcomes or within the terms and time frames initially anticipated, including as a result of increased public involvement, intervention or litigation in such projects;

•Risks and uncertainties that may impact the Companies’ ability to construct the CVOW Commercial Project within the currently proposed timeline, or at all, and consistent with current cost estimates along with the ability to recover such costs from customers;

•Risks and uncertainties associated with the timely receipt of future capital contributions, including optional capital contributions, if any, from Stonepeak associated with the construction of the CVOW Commercial Project;

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•Changes to federal, state and local environmental laws and regulations, including those related to climate change, the tightening of emission or discharge limits for GHGs and other substances, more extensive permitting requirements and the regulation of additional substances;

•Cost of environmental strategy and compliance, including those costs related to climate change;

•Changes in implementation and enforcement practices of regulators relating to environmental standards and litigation exposure for remedial activities;

•Difficulty in anticipating mitigation requirements associated with environmental and other regulatory approvals or related appeals;

•Unplanned outages at facilities in which the Companies have an ownership interest;

•The impact of operational hazards, including adverse developments with respect to plant safety or integrity, equipment loss, malfunction or failure, operator error and other catastrophic events;

•Risks associated with the operation of nuclear facilities, including costs associated with the disposal of spent nuclear fuel, decommissioning, plant maintenance and changes in existing regulations governing such facilities;

•Changes in operating, maintenance or construction costs;

•The availability of nuclear fuel, natural gas, purchased power or other materials utilized by the Companies to provide electric generation, transmission and distribution and/or gas distribution services to their customers;

•Domestic terrorism and other threats to the Companies’ physical and intangible assets, as well as cybersecurity threats or incidents;

•Additional competition in industries in which the Companies operate, including in electric markets in which Dominion Energy’s nonregulated generation facilities operate and potential competition from the development and deployment of alternative energy sources, such as self-generation and distributed generation technologies, and availability of market alternatives to large commercial and industrial customers;

•Competition in the development, construction and ownership of certain electric transmission facilities in the Companies’ service territory in connection with Order 1000;

•Changes in technology, particularly with respect to new, developing or alternative sources of generation and smart grid technologies;

•Changes in demand for the Companies’ services, including industrial, commercial and residential growth or decline in the Companies’ service areas, failure to maintain or replace customer contracts on favorable terms, changes in customer growth or usage patterns, including as a result of energy conservation programs, the availability of energy efficient devices and the use of distributed generation methods;

•Risks and uncertainties associated with increased energy demand or significant accelerated growth in demand due to new data centers, including the concentration of data centers primarily in Loudoun County, Virginia and the ability to obtain regulatory approvals, environmental and other permits to construct new facilities in a timely manner;

•The technological and economic feasibility of large-scale battery storage, carbon capture and storage, small modular reactors, hydrogen and/or other clean energy technologies;

•Receipt of approvals for, and timing of, closing dates for acquisitions and divestitures;

•Impacts of acquisitions, divestitures, transfers of assets to joint ventures or retirements of assets based on asset portfolio reviews;

•Adverse outcomes in litigation matters or regulatory proceedings;

•Counterparty credit and performance risk;

•Fluctuations in the value of investments held in nuclear decommissioning trusts by the Companies and in benefit plan trusts by Dominion Energy;

•Fluctuations in energy-related commodity prices and the effect these could have on Dominion Energy’s earnings and the Companies’ liquidity position and the underlying value of their assets;

•Fluctuations in interest rates;

•Changes in rating agency requirements or credit ratings and their effect on availability and cost of capital;

•Global capital market conditions, including the availability of credit and the ability to obtain financing on reasonable terms;

•Political and economic conditions, including tariffs, inflation and deflation;

•Employee workforce factors, including collective bargaining agreements and labor negotiations with union employees; and

•Changes in financial or regulatory accounting principles or policies imposed by governing bodies.

Additionally, other risks that may cause actual results to differ materially from predicted results are set forth in Part I. Item 1A. Risk Factors in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 and Part II Item 1A. Risk Factors in this report.

The Companies’ forward-looking statements are based on beliefs and assumptions using information available at the time the statements are made. The Companies caution the reader not to place undue reliance on their forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, differ materially from actual results. The Companies undertake no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.

Accounting Matters

At September 30, 2026, there have been no significant changes with regard to the critical accounting policies and estimates disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. The policies disclosed included the accounting for regulated operations, AROs, income taxes, accounting for derivative contracts and financial instruments at fair value, use of estimates in goodwill impairment testing, use of estimates in

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long-lived asset impairment testing, and employee benefit plans.

Results of Operations—Dominion Energy

Presented below is a summary of Dominion Energy’s consolidated results:

		2026				2025				$ Change
(millions, except EPS)
Third Quarter
Net income attributable to Dominion    Energy		$	1,160			$	1,006			$	154
Diluted EPS			1.30				1.16				0.14
Year-to-Date
Net income attributable to Dominion    Energy		$	2,121			$	2,431			$	(310	)
Diluted EPS			2.37				2.81				(0.44	)

Overview

Third Quarter 2026 vs. 2025

Net income attributable to Dominion Energy increased 15%, primarily due to higher rider equity returns reflecting capital investments at Virginia Power and the impacts of the 2025 Biennial Review at Virginia Power, partially offset by a decrease in net investment earnings on nuclear decommissioning trust funds.

Year-to-Date 2026 vs. 2025

Net income attributable to Dominion Energy decreased 13%, primarily due to impairment charges associated with nonregulated renewable natural gas facilities and certain nonregulated solar generation facilities, higher interest on long-term debt, increased unrealized losses on economic hedging activities and increased capacity expense. These decreases were partially offset by a benefit related to the revision of AROs for Millstone Unit 1, higher rider equity returns reflecting capital investments at Virginia Power and the impacts of the 2025 Biennial Review at Virginia Power.

Analysis of Consolidated Operations

Presented below are selected amounts related to Dominion Energy’s results of operations:

		Third Quarter											Year-to-Date
		2026				2025				$ Change			2026			2025			$ Change
(millions)
Operating revenue		$	5,617			$	4,527			$	1,090		$	15,116		$	12,413		$	2,703
Electric fuel and    other    energy-related    purchases			1,603				1,337				266			4,524			3,245			1,279
Purchased electric    capacity			106				36				70			255			63			192
Purchased gas			40				31				9			236			221			15
Other operations    and maintenance			1,070				850				220			3,039			2,631			408
Depreciation and    amortization			722				609				113			1,968			1,771			197
Other taxes			215				195				20			653			598			55
Impairment of    assets and    other charges			19				130				(111	)		878			226			652
Other income    (expense)			271				432				(161	)		952			884			68
Interest and    related charges			623				527				96			1,739			1,513			226
Income tax    expense			215				216				(1	)		385			476			(91	)
Net income    (loss) from    discontinued    operations    including    noncontrolling    interests			(1	)			—				(1	)		(3	)		—			(3	)
Noncontrolling    interests			114				22				92			267			122			145

An analysis of Dominion Energy’s results of operations follows:

Third Quarter 2026 vs. 2025

Operating revenue increased 24%, primarily reflecting:

•A $382 million increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges at Virginia Power;

•A $258 million increase to recover the costs and an authorized return, as applicable, associated with Virginia Power non-fuel riders;

•A $184 million increase associated with the 2025 Biennial Review at Virginia Power;

•A $122 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days;

•A $60 million increase in non-fuel base rates resulting from the settlement of the 2026 electric base rate case in South Carolina;

•A $21 million increase in sales to electric utility retail customers associated with growth; and

•A $17 million increase in sales to electric utility retail customers associated with economic and other usage factors.

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Electric fuel and other energy-related purchases increased 20%, primarily due to higher commodity costs for electric utilities ($363 million), partially offset by a decrease in the use of purchased renewable energy credits ($110 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain Virginia Power generation facilities subject to cost recovery through base rates ($60 million).

Purchased electric capacity increased $70 million, primarily due to an increase related to the net impact from the annual PJM capacity markets at Virginia Power ($97 million), partially offset by a decrease associated with supplemental capacity purchase agreements at Virginia Power ($22 million).

Other operations and maintenance increased 26%, primarily due to an increase in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income ($79 million), an increase in storm damage and restoration costs ($25 million), merger-related costs associated with the proposed NextEra Energy Merger ($23 million), renewable natural gas projects placed in service in late 2025 ($24 million) and an increase in outside services ($22 million).

Depreciation and amortization increased 19%, primarily due to various projects being placed into service ($67 million) and an increase in amortization associated with non-fuel riders ($24 million), which is offset in operating revenue and does not impact net income.

Other taxes increased 10%, primarily due to an increase in property taxes.

Impairment of assets and other charges decreased 85%, primarily due to the absence of a charge for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project.

Other income decreased 37%, primarily due to a decrease in net investment gains on nuclear decommissioning trust funds.

Interest and related charges increased 18%, primarily due to net issuances of long-term debt ($95 million) and increased interest expense associated with rider deferrals ($17 million), which is offset in operating revenue and does not impact net income, partially offset by net unrealized gains in 2026 compared to net unrealized losses in 2025 associated with freestanding derivatives ($22 million).

Noncontrolling interests increased $92 million, due to an increase in earnings from the CVOW Commercial Project, including the absence of a share of a charge for costs not expected to be recovered from customers.

Year-to-Date 2026 vs. 2025

Operating revenue increased 22%, primarily reflecting:

•A $1.3 billion increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges at Virginia Power;

•A $738 million increase to recover the costs and an authorized return, as applicable, associated with Virginia Power non-fuel riders;

•A $466 million increase associated with the 2025 Biennial Review at Virginia Power;

•A $154 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days during the cooling season ($112 million) and an increase in heating degree days during the heating season ($42 million);

•A $71 million increase in non-fuel base rates resulting from the settlement of the 2026 electric base rate case in South Carolina;

•A $52 million increase in sales to electric utility retail customers associated with growth;

•$48 million in sales of renewable natural gas and related environmental credits;

•A $30 million increase in sales to electric utility retail customers associated with economic and other usage factors; and

•A $28 million increase attributable to a service contract with a government entity which commenced in late 2025.

These increases were partially offset by:

•A $159 million net decrease associated with market prices affecting Millstone, including economic hedging impacts of net realized and unrealized losses on freestanding derivatives ($201 million);

•A $60 million decrease associated with severe weather events affecting Virginia Power; and

•A $26 million decrease from the impacts of the capital cost rider in South Carolina.

Electric fuel and other energy-related purchases increased 39%, primarily due to higher commodity costs for electric utilities ($1.2 billion) and an increase in the use of purchased renewable energy credits ($15 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain Virginia Power generation facilities subject to cost recovery through base rates ($60 million).

Purchased electric capacity increased $192 million, primarily due to an increase related to the net impact from the annual PJM capacity markets at Virginia Power ($162 million) and an increase due to clean energy rider costs ($20 million), which is offset in operating revenue and does not impact net income.

Other operations and maintenance increased 16%, primarily reflecting:

•A $100 million increase in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income;

•$81 million due to renewable natural gas projects placed in service in late 2025;

•A $53 million increase in salaries, wages and benefits;

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•A $50 million increase in outside services;

•$34 million in merger-related costs associated with the proposed NextEra Energy Merger; and

•A $29 million increase in outage costs primarily at Virginia Power.

Depreciation and amortization increased 11%, primarily due to various projects being placed into service.

Impairment of assets and other charges increased $652 million, primarily due to a charge associated with nonregulated renewable natural gas facilities ($820 million), charges associated with certain nonregulated solar generation facilities ($79 million) and the disallowance of certain strategic undergrounding costs ($23 million), partially offset by a benefit related to the revision of AROs for Millstone Unit 1 ($195 million) and a decrease in net charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($95 million).

Other income increased 8%, primarily due to an increase in net investment gains on nuclear decommissioning trust funds ($32 million), an increase in AFUDC associated with rate-regulated projects ($27 million) and an increase related to offshore wind installation vessel operations ($18 million), partially offset by a decrease in non-service components of pension and other postretirement employee benefit plan credits ($25 million).

Interest and related charges increased 15%, primarily due to net issuances of long-term debt ($284 million) and an increase in interest on variable rate debt ($17 million), partially offset by net unrealized gains in 2026 compared to net unrealized losses in 2025 associated with freestanding derivatives ($80 million).

Income tax expense decreased 19%, primarily due to lower pre-tax income.

Noncontrolling interests increased $145 million, due to an increase in earnings associated with the CVOW Commercial Project, which includes the share of decreased charges for costs not expected to be recovered from customers.

Results of Operations—Virginia Power

Presented below is a summary of Virginia Power’s consolidated results:

		2026				2025				$ Change
(millions)
Third Quarter
Net income attributable to Virginia    Power		$	880			$	668			$	212
Year-to-Date
Net income attributable to Virginia    Power		$	2,100			$	1,688			$	412

Overview

Third Quarter 2026 vs. 2025

Net income increased 32%, primarily due to higher rider equity returns reflecting capital investments and the impacts of the 2025 Biennial Review.

Year-to-Date 2026 vs. 2025

Net income increased 24%, primarily due to higher rider equity returns reflecting capital investments and the impacts of the 2025 Biennial Review, partially offset by higher interest on long-term debt and increased capacity expense.

Analysis of Consolidated Operations

Presented below are selected amounts related to Virginia Power’s results of operations:

	Third Quarter									Year-to-Date
	2026			2025			$ Change			2026			2025			$ Change
(millions)
Operating revenue	$	4,218		$	3,311		$	907		$	11,335		$	8,788		$	2,547
Electric fuel and    other    energy-related    purchases		1,296			1,071			225			3,739			2,569			1,170
Purchased electric    capacity		103			32			71			246			56			190
Other operations    and maintenance		744			577			167			2,039			1,740			299
Depreciation and    amortization		509			418			91			1,347			1,212			135
Other taxes		104			93			11			309			282			27
Impairment of    assets and other    charges		3			129			(126	)		157			225			(68	)
Other income    (expense)		67			85			(18	)		221			191			30
Interest and related    charges		312			235			77			833			729			104
Income tax expense		220			151			69			519			356			163
Noncontrolling    interests		114			22			92			267			122			145

An analysis of Virginia Power’s results of operations follows:

Third Quarter 2026 vs. 2025

Operating revenue increased 27%, primarily reflecting:

•A $348 million net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges;

•A $258 million increase to recover the costs and an authorized return, as applicable, associated with non-fuel riders;

•A $184 million increase associated with the 2025 Biennial Review;

•A $75 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days;

•A $14 million increase in sales to electric utility retail customers associated with growth; and

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•A $13 million increase in sales to electric utility retail customers associated with economic and other usage factors.

Electric fuel and other energy-related purchases increased 21%, primarily due to higher commodity costs for electric utilities ($329 million), partially offset by a decrease in the use of purchased renewable energy credits ($110 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain generation facilities subject to cost recovery through base rates ($60 million).

Purchased electric capacity increased $71 million, primarily due to an increase related to the net impact from the annual PJM capacity markets ($97 million), partially offset by a decrease associated with supplemental capacity purchase agreements ($22 million).

Other operations and maintenance increased 29%, primarily due to an increase in certain expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income ($79 million), an increase in salaries, wages and benefits and administrative costs ($51 million), an increase in storm damage and restoration costs ($24 million) and an increase in outside services primarily attributable to a service contract with a government entity which commenced in late 2025 ($10 million).

Depreciation and amortization increased 22%, primarily due to various projects being placed into service ($53 million) and an increase in amortization associated with non-fuel riders ($24 million), which is offset in operating revenue and does not impact net income.

Other taxes increased 12%, primarily due to an increase in property taxes.

Impairment of assets and other charges decreased 98%, primarily due to the absence of a charge for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project.

Other income decreased 21%, primarily due to a decrease in net investment gains on nuclear decommissioning trust funds.

Interest and related charges increased 33%, primarily due to an increase in long-term debt borrowings ($50 million) and increased interest expense associated with rider deferrals ($17 million), which is offset in operating revenue and does not impact net income.

Income tax expense increased 46%, primarily due to higher pre-tax income.

Noncontrolling interests increased $92 million, due to an increase in earnings from the CVOW Commercial Project, including the absence of a share of a charge for costs not expected to be recovered from customers.

Year-to-Date 2026 vs. 2025

Operating revenue increased 29%, primarily reflecting:

•A $1.2 billion net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges;

•A $738 million increase to recover the costs and an authorized return, as applicable, associated with non-fuel riders;

•A $466 million increase associated with the 2025 Biennial Review;

•A $113 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days during the cooling season ($70 million) and an increase in heating degree days during the heating season ($43 million);

•A $39 million increase in sales to electric utility retail customers associated with growth;

•A $28 million increase attributable to a service contract with a government entity which commenced in late 2025; and

•A $21 million increase in sales to electric utility retail customers associated with economic and other usage factors.

These increases were partially offset by:

•A $60 million decrease associated with severe weather events.

Electric fuel and other energy-related purchases increased 46%, primarily due to higher commodity costs for electric utilities ($1.2 billion) and an increase in the use of purchased renewable energy credits ($15 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain generation facilities subject to cost recovery through base rates ($60 million).

Purchased electric capacity increased $190 million, primarily due to an increase related to the net impact from the annual PJM capacity markets ($162 million) and an increase due to clean energy rider costs ($20 million), which is offset in operating revenue and does not impact net income.

Other operations and maintenance increased 17%, primarily reflecting:

•A $116 million increase in salaries, wages and benefits and administrative costs;

•A $100 million increase in certain expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income;

•A $36 million increase in outside services primarily attributable to a service contract with a government entity which commenced in late 2025;

•A $24 million increase in outage costs;

•A $13 million increase in materials and supplies expense;

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•A $13 million increase in tree trimming and vegetation management; and

•A $10 million increase in bad debt expense.

Depreciation and amortization increased 11%, primarily due to various projects being placed into service.

Other taxes increased 10%, primarily due to an increase in property taxes.

Impairment of assets and other charges decreased 30%, primarily due to a decrease in net charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($95 million), partially offset by the disallowance of certain strategic undergrounding costs ($23 million).

Other income increased 16%, primarily due to an increase in AFUDC associated with rate-regulated projects.

Interest and related charges increased 14%, primarily due to an increase in long-term debt borrowings ($117 million), partially offset by lower interest rates on commercial paper and intercompany borrowings with Dominion Energy ($10 million).

Income tax expense increased 46%, primarily due to higher pre-tax income.

Noncontrolling interests increased $145 million, due to an increase in earnings associated with the CVOW Commercial Project, which includes the share of decreased charges for costs not expected to be recovered from customers.

Segment Results of Operations

Segment results include the impact of intersegment revenues and expenses, which may result in intersegment profit and loss. Presented below is a summary of contributions by Dominion Energy’s operating segments to net income (loss) attributable to Dominion Energy:

		Net Income (Loss) Attributable to Dominion Energy												EPS(1)
		2026				2025				$ Change				2026				2025				$ Change
(millions, except EPS)
Third Quarter
Dominion Energy Virginia		$	862			$	679			$	183			$	0.98			$	0.79			$	0.19
Dominion Energy South Carolina			230				168				62				0.26				0.20				0.06
Contracted Energy			134				165				(31	)			0.15				0.19				(0.04	)
Corporate and Other			(66	)			(6	)			(60	)			(0.09	)			(0.02	)			(0.07	)
Consolidated		$	1,160			$	1,006			$	154			$	1.30			$	1.16			$	0.14
Year-to-Date
Dominion Energy Virginia		$	2,202			$	1,789			$	413			$	2.51			$	2.10			$	0.41
Dominion Energy South Carolina			461				429				32				0.52				0.50				0.02
Contracted Energy			284				321				(37	)			0.32				0.38				(0.06	)
Corporate and Other			(826	)			(108	)			(718	)			(0.98	)			(0.17	)			(0.81	)
Consolidated		$	2,121			$	2,431			$	(310	)		$	2.37			$	2.81			$	(0.44	)

(1)Consolidated results are presented on a diluted EPS basis. The dilutive impacts, primarily consisting of potential shares which had not yet been issued, are included within the results of the Corporate and Other segment. EPS contributions for Dominion Energy’s operating segments are presented utilizing basic average shares outstanding for the period.

Dominion Energy Virginia

Presented below are selected operating statistics related to Dominion Energy Virginia’s operations:

		Third Quarter												Year-to-Date
		2026				2025				% Change				2026				2025				% Change
Electricity delivered (million MWh)			29.4				27.0				9		%		80.6				76.1				6		%
Electricity supplied (million MWh):
Utility			29.4				27.1				8				80.6				76.2				6
Non-Jurisdictional			0.4				0.5				(20	)			1.3				1.4				(7	)
Degree days (electric distribution and utility service area):
Cooling			1,313				1,066				23				1,925				1,698				13
Heating			8				—			N/A					2,277				2,118				8
Average electric distribution customer accounts    (thousands)			2,835				2,811				1				2,830				2,805				1

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Presented below, on an after-tax basis, are the key factors impacting Dominion Energy Virginia’s net income contribution:

		Third Quarter 2026 vs. 2025 Increase (Decrease)								Year-to-Date 2026 vs. 2025 Increase (Decrease)
		Amount				EPS				Amount				EPS
(millions, except EPS)
Weather		$	55			$	0.06			$	84			$	0.10
Customer usage and other factors			19				0.02				44				0.05
2025 Biennial Review impacts(1)			137				0.16				347				0.41
Rider equity return			112				0.13				275				0.32
Electric capacity			(48	)			(0.06	)			(124	)			(0.15	)
Storm damage and restoration costs			(16	)			(0.02	)			(30	)			(0.04	)
Planned outage costs			(6	)			(0.01	)			(18	)			(0.02	)
Nuclear production tax credit			(17	)			(0.02	)			(48	)			(0.06	)
Depreciation and amortization			(16	)			(0.02	)			(36	)			(0.04	)
Salaries, wages and benefits & administrative costs			(33	)			(0.04	)			(81	)			(0.09	)
Interest expense, net			(12	)			(0.01	)			(5	)			(0.01	)
Other			8				0.03				5				0.02
Share dilution			—				(0.03	)			—				(0.08	)
Change in net income contribution		$	183			$	0.19			$	413			$	0.41

(1)Includes the impacts of non-jurisdictional customers.

Dominion Energy South Carolina

Presented below are selected operating statistics related to Dominion Energy South Carolina’s operations:

		Third Quarter												Year-to-Date
		2026				2025				% Change				2026				2025				% Change
Electricity delivered (million MWh)			7.1				6.4				11		%		18.0				17.2				5		%
Electricity supplied (million MWh)			7.4				6.7				10				18.9				18.0				5
Degree days (electric distribution service areas):
Cooling			748				498				50				1,004				767				31
Heating			—				—				—				821				853				(4	)
Gas distribution throughput (bcf):
Sales			15				13				15				53				50				6
Average distribution customer accounts (thousands):
Electric			834				822				1				831				816				2
Gas			486				474				3				483				471				3

Presented below, on an after-tax basis, are the key factors impacting Dominion Energy South Carolina’s net income contribution:

		Third Quarter 2026 vs. 2025 Increase (Decrease)								Year-to-Date 2026 vs. 2025 Increase (Decrease)
		Amount				EPS				Amount				EPS
(millions, except EPS)
Weather		$	36			$	0.04			$	31			$	0.04
Customer usage and other factors			19				0.02				42				0.05
Customer-elected rate impacts			1				—				(1	)			—
Base rate case & Natural Gas Rate Stabilization Act impacts			46				0.05				59				0.07
Capital cost rider			(1	)			—				(5	)			(0.01	)
Depreciation and amortization			(16	)			(0.02	)			(29	)			(0.03	)
Salaries, wages and benefits & administrative costs			(3	)			—				(3	)			—
Interest expense, net			(7	)			(0.01	)			(11	)			(0.01	)
Other			(13	)			(0.01	)			(51	)			(0.07	)
Share dilution			—				(0.01	)			—				(0.02	)
Change in net income contribution		$	62			$	0.06			$	32			$	0.02

Contracted Energy

Presented below are selected operating statistics related to Contracted Energy’s operations:

		Third Quarter												Year-to-Date
		2026				2025				% Change				2026				2025				% Change
Electricity supplied (million MWh)			5.1				5.0				2		%		14.2				13.9				2		%
Renewable natural gas supplied (million MMBtu)			0.5				—			N/A					1.4				—			N/A

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Presented below, on an after-tax basis, are the key factors impacting Contracted Energy’s net income contribution:

		Third Quarter 2026 vs. 2025 Increase (Decrease)								Year-to-Date 2026 vs. 2025 Increase (Decrease)
		Amount				EPS				Amount				EPS
(millions, except EPS)
Margin		$	22			$	0.03			$	100			$	0.12
Planned Millstone outages(1)			3				—				7				0.01
Unplanned Millstone outages(1)			(2	)			—				(5	)			(0.01	)
Depreciation and amortization			(7	)			(0.01	)			(39	)			(0.05	)
Renewable energy investment tax credits			(43	)			(0.05	)			(33	)			(0.04	)
Renewable energy production tax credits(2)			36				0.04				57				0.07
Salaries, wages and benefits & administrative costs			(3	)			—				(11	)			(0.01	)
Interest expense, net			(10	)			(0.01	)			(41	)			(0.05	)
Other			(27	)			(0.04	)			(72	)			(0.09	)
Share dilution			—				—				—				(0.01	)
Change in net income contribution		$	(31	)		$	(0.04	)		$	(37	)		$	(0.06	)

(1)Includes earnings impact from outage costs and lower energy margins.

(2)Includes an increase from renewable natural gas facilities of $37 million and $57 million for the quarter and year-to-date periods, respectively.

Corporate and Other

Presented below are the Corporate and Other segment’s after-tax results:

		Third Quarter												Year-to-Date
		2026				2025				$ Change				2026				2025				$ Change
(millions, except EPS)
Specific items attributable to operating segments		$	35			$	88			$	(53	)		$	(572	)		$	81			$	(653	)
Specific items attributable to Corporate and Other    segment			(14	)			(3	)			(11	)			(5	)			(23	)			18
Net income (expense) from specific items			21				85				(64	)			(577	)			58				(635	)
Corporate and other operations:
Interest expense, net			(166	)			(147	)			(19	)			(485	)			(370	)			(115	)
Equity method investments			2				—				2				2				(5	)			7
Pension and other postretirement benefit plans			62				58				4				187				172				15
Corporate service company costs			(16	)			(14	)			(2	)			(43	)			(39	)			(4	)
Other			31				12				19				90				76				14
Net expense from corporate and other operations			(87	)			(91	)			4				(249	)			(166	)			(83	)
Total net expense		$	(66	)		$	(6	)		$	(60	)		$	(826	)		$	(108	)		$	(718	)
EPS impact		$	(0.09	)		$	(0.02	)		$	(0.07	)		$	(0.98	)		$	(0.17	)		$	(0.81	)

Corporate and Other includes specific items attributable to Dominion Energy’s primary operating segments that are not included in profit measures evaluated by executive management in assessing the segments’ performance or in allocating resources. See Note 20 to the Consolidated Financial Statements in this report for discussion of these items in more detail. Corporate and Other also includes items attributable to the Corporate and Other segment. For the three months ended September 30, 2026, this primarily included $25 million of after-tax charges for merger-related costs. For the nine months ended September 30, 2026, this primarily included $37 million of after-tax charges for merger-related costs and $36 million after-tax benefit for derivative mark-to-market changes. For the three months ended September 30, 2025, Dominion Energy reported an insignificant amount of specific items in the Corporate and Other segment. For the nine months ended September 30, 2025, this primarily included $23 million after-tax loss for derivative mark-to-market changes.

Outlook

At September 30, 2026, there have been no material changes to Dominion Energy’s 2026 outlook as described in Item 7. MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. See Future Issues and Other Matters for a discussion of certain items that may have an impact on Dominion Energy’s 2026 net income on a per share basis.

Liquidity and Capital Resources

Dominion Energy depends on both cash generated from operations and external sources of liquidity to provide working capital and as a bridge to long-term financings. Dominion Energy’s material cash requirements include capital and investment expenditures, repaying short-term and long-term debt obligations and paying dividends on its common and preferred stock.

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Analysis of Cash Flows

Presented below are selected amounts related to Dominion Energy’s cash flows:

		2026				2025
(millions)
Cash, restricted cash and equivalents at    January 1		$	343			$	365
Cash flows provided by (used in):
Operating activities(1)			4,688				4,374
Investing activities			(8,749	)			(9,501	)
Financing activities			4,281				5,828
Net increase in cash, restricted cash    and equivalents			220				701
Cash, restricted cash and equivalents at    September 30		$	563			$	1,066

(1)Includes cash outflows of $49 million and $55 million for energy efficiency programs in Virginia for the nine months ended September 30, 2026 and 2025, respectively, and $21 million and $19 million for DSM programs in South Carolina for the nine months ended September 30, 2026 and 2025, respectively.

Operating Cash Flows

Net cash provided by Dominion Energy’s operating activities increased $314 million, primarily due to higher operating cash flows from electric utility operations driven by riders and impacts from the 2025 Biennial Review ($733 million) and lower net prepayments and deposits ($371 million), partially offset by an increase in interest payments primarily driven by higher borrowings ($430 million), a decrease from changes in working capital ($205 million) and lower settlements of interest rate swaps ($155 million).

Investing Cash Flows

Net cash used in Dominion Energy’s investing activities decreased $752 million, primarily due to timing of payments for plant construction and other property additions.

Financing Cash Flows

Net cash from Dominion Energy's financing activities decreased $1.5 billion, primarily due to a decrease in net issuances of long-term debt ($1.7 billion) and a decrease in capital contributions from Stonepeak to OSWP, net of distributions from OSWP to Stonepeak ($714 million), partially offset by an increase in net issuances of short-term debt ($829 million) and the absence of impacts from the sale of a noncontrolling interest in OSWP ($88 million).

Credit Facilities and Short-Term Debt

As discussed in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, Dominion Energy generally uses proceeds from short-term borrowings, including commercial paper, to satisfy short-term cash requirements not met through cash from operations. The levels of borrowing may vary significantly during the course of the year, depending on the timing and amount of cash requirements not satisfied by cash from operations. There have been no significant changes to Dominion Energy’s use of credit facilities and/or short-term debt during the nine months ended September 30, 2026.

Revolving Credit Facilities

Dominion Energy’s short-term financing is primarily supported by its $7.0 billion joint revolving credit facility. At September 30, 2026, Dominion Energy had $5.1 billion of unused capacity under its revolving credit facilities. In April 2026, Dominion Energy’s $1.0 billion 364-day revolving credit facility matured. Subsequently, in April 2026, Dominion Energy entered into a $1.0 billion supplemental revolving credit facility which matures in April 2028. This credit facility can be used to support bank borrowings and the issuance of commercial paper. See Note 15 to the Consolidated Financial Statements in this report for the balances of commercial paper and letters of credit outstanding and for additional information on the revolving credit facilities.

Dominion Energy Reliability InvestmentSM Program

Dominion Energy has an effective shelf registration statement with the SEC for the sale of up to $3.0 billion of variable denomination floating rate demand notes, called Dominion Energy Reliability InvestmentSM. The registration limits the principal amount that may be outstanding at any one time to $1.0 billion. The notes are offered on a continuous basis and bear interest at a floating rate per annum determined by the Dominion Energy Reliability Investment Committee, or its designee, on a weekly basis. The notes have no stated maturity date, are non-transferable and may be redeemed in whole or in part by Dominion Energy or at the investor’s option at any time. At September 30, 2026, Dominion Energy’s Consolidated Balance Sheet included $369 million presented within short-term debt. The proceeds are used for general corporate purposes and to repay debt.

Other Facilities

In addition to the primary sources of short-term liquidity discussed above, from time to time Dominion Energy enters into separate supplementary credit facilities or term loans as discussed in Note 15 to the Consolidated Financial Statements in this report. In February 2026, Dominion Energy entered into an approximately $1.3 billion 364-day term loan facility as described in Note 17 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. Prior to the termination of the facility in August 2026, Dominion Energy borrowed and repaid the full capacity of the facility with the proceeds used to repay existing debt and for general corporate purposes.

Long-Term Debt

Sustainability Revolving Credit Agreement

Dominion Energy maintains a Sustainability Revolving Credit Agreement which is described in Note 18 to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025. At September 30, 2026, Dominion Energy had no borrowings outstanding under this facility. See Note 15 to the Consolidated Financial Statements in this report for borrowings and repayments made during the nine months ended September 30, 2026.

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Issuances and Borrowings of Long-Term Debt

During the nine months ended September 30, 2026, Dominion Energy issued or borrowed the following long-term debt. Unless otherwise noted, the proceeds were used for the repayment of existing indebtedness and for general corporate purposes.

Month		Type		Public / Private		Entity		Principal				Rate					Stated Maturity
								(millions)
March		Senior notes		Public		Virginia Power		$	1,300				4.950		%		2036
March		Senior notes		Public		Virginia Power			850				5.700		%		2056
June		Senior notes		Public		Dominion Energy			825				5.350		%		2036
June		Junior subordinated notes		Public		Dominion Energy			1,000				6.150		%	(1)	2056
June		Junior subordinated notes		Public		Dominion Energy			500				6.250		%	(1)	2056
August		Senior notes		Public		Virginia Power			1,250				5.650		%		2036
August		Senior notes		Public		Virginia Power			700				6.300		%		2056
September		First mortgage bonds		Public		DESC			300				6.150		%		2056
Total issuances and borrowings								$	6,725

(1)Rate subject to periodic reset as described in Note 15 to the Consolidated Financial Statements in this report.

Dominion Energy currently meets the definition of a well-known seasoned issuer under SEC rules governing the registration, communication and offering processes under the Securities Act of 1933, as amended. The rules provide for a streamlined shelf registration process to provide registrants with timely access to capital. This allows Dominion Energy to use automatic shelf registration statements to register any offering of securities, other than those for exchange offers or business combination transactions.

Dominion Energy anticipates, excluding potential opportunistic financings, issuing between approximately $6.0 billion and $9.5 billion of long-term debt during 2026, inclusive of amounts issued through September 30, 2026 as shown in the table above. Dominion Energy expects to issue long-term debt to satisfy cash needs for capital expenditures, net of reimbursements from Stonepeak for the CVOW Commercial Project, and maturing long-term debt to the extent such amounts are not satisfied from cash available from operations following the payment of dividends and any borrowings made from unused capacity of Dominion Energy’s credit facilities discussed above. The raising of external capital is subject to certain regulatory requirements, including registration with the SEC for certain issuances.

Repayments, Repurchases and Redemptions of Long-Term Debt

Dominion Energy may from time to time reduce its outstanding debt and level of interest expense through redemption of debt securities prior to maturity or repurchases of debt securities in the open market, in privately negotiated transactions, through tender offers or otherwise.

The following long-term debt was repaid, repurchased or redeemed during the nine months ended September 30, 2026:

Month

Type

Entity

Principal (1)

Rate

Stated Maturity

(millions)

Debt scheduled to mature in 2026

Multiple

$

1,798

various

Early repurchases and redemptions

None

Total repayments, repurchases and redemptions

$

1,798

(1)Total amount redeemed prior to maturity, if any, includes remaining principal plus accrued interest.

See Note 18 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 for additional information regarding scheduled maturities of Dominion Energy’s long-term debt, including related average interest rates.

Remarketing of Long-Term Debt

During the nine months ended September 30, 2026, Dominion Energy was not required to and did not complete the remarketing of any of its long-term debt. In 2026, Dominion Energy does not expect to remarket any of its tax-exempt bonds.

Credit Ratings

As discussed in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, Dominion Energy’s credit ratings affect its liquidity, cost of borrowing under credit facilities and collateral posting requirements under commodity contracts, as well as the rates at which it is able to offer its debt securities. The credit ratings for Dominion Energy are affected by its financial profile, mix of regulated and nonregulated businesses and respective cash flows, changes in methodologies used by the rating agencies and event risk, if applicable, such as major acquisitions or dispositions. A credit rating is not a recommendation to buy, sell or hold securities and should be evaluated independently of any other rating. Ratings are subject to revision or withdrawal at any time by the applicable rating organization. In May 2026, Dominion Energy’s credit ratings were revised as follows: Moody’s affirmed its credit ratings and revised its outlook from negative to positive; Standard & Poor’s affirmed its credit ratings and revised its outlook from stable to positive; and Fitch affirmed its credit ratings and revised its outlook from stable to positive watch. At September 30, 2026, there have been no other changes in Dominion Energy’s credit ratings from those described in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

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Financial Covenants

As discussed in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, Dominion Energy is subject to various covenants present in the agreements underlying Dominion Energy’s debt. At September 30, 2026, there have been no material changes to these covenants, nor any events of default under these covenants.

As discussed in Note 15 to the Consolidated Financial Statements of this report, in April 2026, Dominion Energy entered into a new $1.0 billion credit facility, which includes a maximum allowed total debt to total capital ratio that is consistent with the allowed ratio under its joint revolving credit facility.

Common Stock, Preferred Stock and Other Equity Securities

In the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, there is a discussion of Dominion Energy’s existing equity financing programs, including Dominion Energy Direct®. In May 2026, Dominion Energy began purchasing its common stock on the open market for these direct stock purchase plans. During the nine months ended September 30, 2026, Dominion Energy issued $40 million of stock through these programs, net of fees and commissions.

During the third quarter of 2025, Dominion Energy entered into forward sale agreements under its May 2024 at-the-market program for approximately 2.4 million shares of its common stock expected to be settled by the fourth quarter of 2027 at a weighted-average initial forward price of $59.91 per share.

In February 2025, Dominion Energy entered into a new at-the-market-program, and during the second quarter of 2025, Dominion Energy entered into forward sale agreements for approximately 11.0 million shares of its common stock expected to be settled in the fourth quarter of 2026 at a weighted-average initial forward price of $55.83 per share. During the third quarter of 2025, Dominion Energy entered into forward sale agreements for approximately 9.6 million shares of its common stock expected to be settled by the fourth quarter of 2027 at a weighted-average initial forward price of $61.11 per share. In December 2025, Dominion Energy provided notice to elect physical settlement of approximately 5.4 million shares under these forward sales agreements, and in December 2025 settled the agreements at a weighted-average final forward price of $60.44 per share.

In October 2025, Dominion Energy increased the maximum amount of capacity available under its February 2025 at-the-market program by $1.8 billion.

During the first quarter of 2026, Dominion Energy entered into forward sale agreements under its February 2025 at-the-market program for approximately 3.2 million shares of its common stock expected to be settled by the fourth quarter of 2027 at a weighted-average initial forward price of $62.96 per share. During the second quarter of 2026, Dominion Energy entered into forward sale agreements for approximately 7.9 million shares of its common stock expected to be settled by the fourth quarter of 2026 at a weighted-average initial forward price of $67.88 per share. See Note 15 to the Consolidated Financial Statements in this report for additional information.

Through September 30, 2026, Dominion Energy has not repurchased and does not plan to repurchase shares of common stock in 2026, except for shares tendered by employees to satisfy tax withholding obligations on vested restricted stock, which does not impact the available capacity under its stock repurchase authorization. See Note 15 to the Consolidated Financial Statements in this report for additional information.

Capital Expenditures

At September 30, 2026, there have been no material changes to Dominion Energy’s expectation for planned capital expenditures as disclosed in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Dividends

Dominion Energy believes that its operations provide a stable source of cash flow to contribute to planned levels of capital expenditures and maintain or grow the dividend on common shares. See Notes 1 and 15 to the Consolidated Financial Statements in this report for additional information regarding certain dividend restrictions under the NextEra Energy Merger Agreement and Dominion Energy’s outstanding preferred stock and associated dividend rate, respectively.

Subsidiary Dividend Restrictions

At September 30, 2026, there have been no material changes to the subsidiary dividend restrictions disclosed in the Subsidiary Dividend Restrictions section of MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Collateral and Credit Risk

Collateral requirements are impacted by capital projects, commodity prices, hedging levels, Dominion Energy’s credit ratings and the credit quality of its counterparties. At September 30, 2026, there have been no material changes to the collateral requirements disclosed in the Collateral and Credit Risk section of MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Dominion Energy’s exposure to potential concentrations of credit risk results primarily from its energy marketing and price risk management activities. Presented below is a summary of Dominion Energy’s credit exposure at September 30, 2026 for these activities. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights.

		Gross Credit Exposure				Credit Collateral				Net Credit Exposure
(millions)
Investment grade(1)		$	485			$	—			$	485
Non-investment grade(2)			1				—				1
No external ratings:
Internally rated—investment grade(3)			305				10				295
Internally rated—non-investment grade(4)			8				3				5
Total(5)		$	799			$	13			$	786

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(1)Designations as investment grade are based upon minimum credit ratings assigned by Moody’s and Standard & Poor’s. The five largest counterparty exposures, combined, for this category represented approximately 61% of the total net credit exposure.

(2)The five largest counterparty exposures, combined, for this category represented less than 1% of the total net credit exposure.

(3)The five largest counterparty exposures, combined, for this category represented approximately 38% of the total net credit exposure.

(4)The five largest counterparty exposures, combined, for this category represented less than 1% of the total net credit exposure.

(5)Excludes long-term purchase power agreements entered to satisfy legislative or state regulatory commission requirements.

Fuel and Other Purchase Commitments

There have been no material changes outside of the ordinary course of business to Dominion Energy’s fuel and other purchase commitments included in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

Other Material Cash Requirements

In addition to the financing arrangements discussed above, Dominion Energy is party to numerous contracts and arrangements obligating it to make cash payments in future years. Dominion Energy expects current liabilities to be paid within the next twelve months. In addition to the items already discussed, the following represent material expected cash requirements recorded on Dominion Energy’s Consolidated Balance Sheet at September 30, 2026. Such obligations include:

•Operating and finance lease obligations – See Note 13 to the Consolidated Financial Statements in this report and Note 15 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025;

•Regulatory liabilities – See Note 11 to the Consolidated Financial Statements in this report;

•AROs – See Note 2 to the Consolidated Financial Statements in this report and Note 14 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025;

•Employee benefit plan obligations – See Note 19 to the Consolidated Financial Statements in this report and Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025; and

•High load equipment deposits – See Note 2 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

In addition, Dominion Energy is party to contracts and arrangements which may require it to make material cash payments in future years that are not recorded on its Consolidated Balance Sheets. Such obligations include:

•Guarantees – See Note 16 to the Consolidated Financial Statements in this report.

Future Issues and Other Matters

See Item 1. Business, Future Issues and Other Matters in MD&A and Notes 13 and 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025, Future Issues and Other Matters in the Companies’ Quarterly Report on Form 10-Q for the quarters ended March 31, 2026 and June 30, 2026 and Notes 1, 12 and 16 to the Consolidated Financial Statements in this report for additional information on the proposed NextEra Energy Merger as well as various environmental, regulatory, legal and other matters that may impact future results of operations, financial condition and/or cash flows.

CVOW Commercial Project

In September 2019, Virginia Power filed applications with PJM for the CVOW Commercial Project and for certain approvals and rider recovery from the Virginia Commission in November 2021. Installation of the final turbines comprising the 2.6 GW project is expected to be completed by the end of 2027. The estimated total project cost is approximately $11.7 billion (excluding financing costs and including $0.1 billion of contingency) which continues to reflect revised network upgrade costs assigned by PJM to the CVOW Commercial Project, an estimated impact of certain tariffs which became effective in April 2026 and updated turbine installation projections as well as previously included estimated impacts of a temporary suspension of work order, certain tariffs including those which became effective during 2025, the impact of the U.S. Supreme Court’s ruling in late February 2026 and tariffs which became effective in late February 2026. The Companies’ projected impact of tariffs on expected total project cost is subject to change due to the inherent uncertainty associated with which tariffs, if any, may be in effect and the associated requirements and rates of such tariffs. Virginia Power’s estimate for the project’s projected levelized cost of energy, including renewable energy credits, is approximately $62/MWh, compared to the initial filing submission of $80-90/MWh.

The expected total project cost is unchanged from Virginia Power’s July 2026 construction update filing and reflects a decrease of approximately $0.4 billion relative to Virginia Power’s January 2026 construction update filing, associated with a revision to projected onshore electrical interconnection costs and network upgrade costs allocated by PJM to the CVOW Commercial Project. The expected total project cost also reflects an increase of approximately $0.4 billion, relative to Virginia Power’s January 2026 construction update filing, $0.3 billion of which is associated with updated projections for turbine installations reflecting weather and other conditions with the remainder associated with other factors experienced, including increased fuel costs, during installations completed through July 2026. Relative to Virginia Power’s January 2026 construction update filing, the expected impact of tariffs on the expected total project cost is a net increase of approximately $0.1 billion as the increase of approximately $0.2 billion associated with revised Section 232 tariffs enacted in April 2026 on equipment expected to be delivered from April 2026 through the end of 2027 that contains steel, aluminum and/or copper products, including the associated impact such revised tariffs had on tariffs enacted in late February 2026 on equipment expected to be delivered

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from February 2026 through July 2026 that originates from Mexico, Canada, a European Union member or other applicable countries is partially offset by the reversal 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 in late February 2026, and the estimated impact of new tariffs subsequently enacted in late February 2026 on equipment expected to be delivered from February 2026 through July 2026 that originates from Mexico, Canada, a European Union member or other applicable countries. The actual tariffs to be incurred are dependent upon the tariff requirements and rates, if any, at the time of delivery of the specific component.

The estimated total project cost above reflects the Companies’ best estimate of the remaining construction costs, including contingency of approximately 8% on such remaining amounts. Such estimate could potentially change for items, certain of which are beyond the Companies’ control, including but not limited to fuel for transportation and installation, the impact of applicable tariffs including any potential impact of Section 232 investigations, costs to maintain necessary permits, approvals and authorizations, any additional suspension of work orders, ability of key suppliers and contractors to timely satisfy their obligations under existing contracts, marine wildlife, actual network upgrade costs allocated by PJM, adverse weather and/or any severe weather events.

Virginia Power commenced major onshore construction activities for the CVOW Commercial Project in November 2023 following the receipt of a record of decision from BOEM in October 2023 for construction. Onshore construction activities to support first power delivery were completed in December 2025 with remaining project activities to support commercial operations substantially completed in October 2026. Virginia Power commenced major offshore construction activities in May 2024 following the receipt of final approval from BOEM authorizing offshore construction and necessary permits from the U.S. Army Corps of Engineers for offshore construction in January 2024. Virginia Power completed the installation of all monopiles in October 2025 and of all transition pieces in April 2026. The first of three offshore substations was installed in March 2025, with the second installed in November 2025 and the third installed in February 2026. Deepwater cables commenced being laid in late 2024 with the last of nine completed in July 2025. Of the 176 segments of interarray cable, expected to total 260 miles, 143 have been installed through October 2026 with the remaining expected to be laid throughout 2026. Installation commenced on turbines in December 2025 prior to being delayed by the temporary suspension of work order, with 44 of 176 completed through October 2026. The first turbines and associated infrastructure of the CVOW Commercial Project commenced operations in March 2026.

Proposed and/or Recently Issued EPA Rules

In September 2026, the EPA finalized a rule repealing the majority of a package of rules the EPA finalized in May 2024 designed to reduce CO2 emissions from certain fossil fuel-fired electric generating units. The May 2024 final rule set standards of performance and emission guidelines for CO2 emissions from new and reconstructed gas-fired combustion turbines and modified coal-fired steam generating units. The May 2024 rulemaking package also included emission guidelines, including emission limits, for existing coal, oil and gas-fired steam generating units. Until the EPA ultimately takes final action on the proposed rulemakings included in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 within Future Issues and Other Matters in MD&A and publishes all 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. The effects of these proposed rulemakings could have a material impact on Dominion Energy’s financial condition and cash flows.

Investment in Valley Link

In October 2024, Dominion Energy announced a joint planning initiative with AEP and FirstEnergy. As part of the initiative, the companies jointly submitted initial project proposals for high-voltage transmission lines in Virginia, Maryland and West Virginia to PJM. In February 2025, Dominion Energy, AEP and FirstEnergy entered into an agreement for the operation of Valley Link to undertake a multi-year process to develop, construct and subsequently operate the new transmission line projects selected by PJM. Under the terms of the joint venture agreement, Dominion Energy will hold a 30% initial interest in Valley Link. Dominion Energy expects to invest approximately $1.5 billion from 2026 through 2030 in connection with this arrangement.

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ITEM 3. QUANTITATIVE AND QUALITATIVE

DISCLOSURES ABOUT MARKET RISK

The matters discussed in this Item may contain “forward-looking statements” as described in the introductory paragraphs under Part I., Item 2. MD&A in this report. The reader’s attention is directed to those paragraphs for discussion of various risks and uncertainties that may impact the Companies.

Market Risk Sensitive Instruments and Risk Management

The Companies’ financial instruments, commodity contracts and related financial derivative instruments are exposed to potential losses due to adverse changes in commodity prices, interest rates, foreign currency exchange rates and equity securities prices as described below. Commodity price risk is present in the Companies’ electric operations and Dominion Energy’s natural gas procurement and marketing operations due to the exposure to market shifts in prices received and paid for electricity, natural gas and other commodities. The Companies use commodity derivative contracts to manage price risk exposures for these operations. Interest rate risk is generally related to their outstanding debt and future issuances of debt. In addition, the Companies are exposed to investment price risk through various portfolios of equity and debt securities. The Companies’ exposure to foreign currency exchange rate risk is related to certain fixed price contracts associated with the CVOW Commercial Project which it manages through foreign currency exchange rate derivatives. The contracts include services denominated in currencies other than the U.S. dollar for approximately €2.6 billion and 5.1 billion kr. In addition, certain of the fixed price contracts, approximately €0.7 billion, contain commodity indexing provisions linked to steel.

The following sensitivity analyses estimate the potential loss of future earnings or fair value from market risk sensitive instruments over a selected time period due to a 10% change in commodity prices, interest rates or foreign currency exchange rates.

Commodity Price Risk

To manage price risk, the Companies hold commodity-based derivative instruments held for non-trading purposes associated with purchases and sales of electricity, natural gas and other energy-related products.

The derivatives used to manage commodity price risk are executed within established policies and procedures and may include instruments such as futures, forwards, swaps, options and FTRs that are sensitive to changes in the related commodity prices. For sensitivity analysis purposes, the hypothetical change in market prices of commodity-based derivative instruments is determined based on models that consider the market prices of commodities in future periods, the volatility of the market prices in each period, as well as the time value factors of the derivative instruments. Prices and volatility are principally determined based on observable market prices.

A hypothetical 10% decrease in commodity prices would have resulted in a decrease of $47 million and $15 million in the fair value of Dominion Energy’s commodity-based derivative instruments at September 30, 2026 and December 31, 2025, respectively.

A hypothetical 10% decrease in commodity prices would have resulted in a decrease of $96 million and $71 million in the fair value of Virginia Power’s commodity-based derivative instruments at September 30, 2026 and December 31, 2025, respectively.

The impact of a change in energy commodity prices on the Companies’ commodity-based derivative instruments at a point in time is not necessarily representative of the results that will be realized when the contracts are ultimately settled. Net losses from commodity-based financial derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction, such as revenue from physical sales of the commodity.

Interest Rate Risk

The Companies manage their interest rate risk exposure predominantly by maintaining a balance of fixed and variable rate debt. For variable rate debt outstanding for Dominion Energy, a hypothetical 10% increase in market interest rates would result in a $14 million and $10 million decrease in earnings at September 30, 2026 and December 31, 2025, respectively. For variable rate debt outstanding for Virginia Power, a hypothetical 10% increase in market interest rates would result in a $4 million and $7 million decrease in earnings at September 30, 2026 and December 31, 2025, respectively.

The Companies also use interest rate derivatives, including forward-starting swaps, interest rate swaps and interest rate lock agreements to manage interest rate risk. At September 30, 2026, Dominion Energy and Virginia Power had $8.5 billion and $7.4 billion, respectively, in aggregate notional amounts of these interest rate derivatives outstanding in combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of $408 million and $372 million, respectively, in the fair value of Dominion Energy and Virginia Power’s interest rate derivatives at September 30, 2026. At December 31, 2025, Dominion Energy and Virginia Power had $10.7 billion and $8.1 billion, respectively, of these interest rate derivatives outstanding in combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of $459 million and $382 million, respectively, in the fair value of Dominion Energy and Virginia Power’s interest rate derivatives at December 31, 2025.

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The impact of a change in interest rates on the Companies’ interest rate-based financial derivative instruments at a point in time is not necessarily representative of the results that will be realized when the contracts are ultimately settled. Net gains and/or losses from interest rate derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction.

Foreign Currency Exchange Rate Risk

The Companies utilize foreign currency exchange rate swaps to economically hedge the foreign currency exchange risk associated with fixed price contracts related to the CVOW Commercial Project denominated in foreign currencies. At September 30, 2026 and December 31, 2025, Dominion Energy had €0.1 billion and €0.9 billion in aggregate notional amounts of these foreign currency forward purchase agreements outstanding, respectively. A hypothetical 10% increase in the U.S. dollar to Euro exchange rate would have resulted in a decrease of $11 million and $35 million in the fair value of Dominion Energy’s foreign currency swaps at September 30, 2026 and December 31, 2025, respectively.

The impact of a change in exchange rates on the Companies’ foreign currency-based financial derivative instruments at a point in time is not necessarily representative of the results that will be realized when the contracts are ultimately settled. Net gains and/or losses from foreign exchange derivative instruments used for hedging purposes, to the extent realized, will generally be offset by recognition of the hedged transaction.

Investment Price Risk

The Companies are subject to investment price risk due to securities held as investments in nuclear decommissioning and rabbi trust funds that are managed by third-party investment managers. These trust funds primarily hold marketable securities that are reported in the Companies’ Consolidated Balance Sheets at fair value.

Dominion Energy recognized net investment gains (losses) (including investment income) on nuclear decommissioning and rabbi trust investments of $944 million, $854 million and $1.1 billion for the nine months ended September 30, 2026 and 2025 and the year ended December 31, 2025, respectively. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Dominion Energy recorded in AOCI and regulatory liabilities, a net increase in unrealized (losses) gains on debt investments of $(9) million, $52 million and $41 million for the nine months ended September 30, 2026 and 2025 and the year ended December 31, 2025, respectively.

Virginia Power recognized net investment gains (losses) (including investment income) on nuclear decommissioning and rabbi trust investments of $500 million, $436 million and $555 million for the nine months ended September 30, 2026 and 2025 and the year ended December 31, 2025, respectively. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Virginia Power recorded in AOCI and regulatory liabilities, a net increase in unrealized gains (losses) on debt investments of $(6) million, $23 million and $23 million for the nine months ended September 30, 2026 and 2025 and the year ended December 31, 2025, respectively.

Dominion Energy sponsors pension and other postretirement employee benefit plans that hold investments in trusts to fund employee benefit payments. Virginia Power employees participate in these plans. Differences between actual and expected returns on plan assets are immediately recognized in earnings annually in the fourth quarter of each fiscal year as well as whenever a plan is determined to qualify for a remeasurement. A hypothetical 0.25% decrease in the expected long-term rate of return on plan assets would have a $27 million impact for the year ending December 31, 2026, and would have had a $28 million impact for the year ended December 31, 2025, to the expected returns on plan assets, respectively.

ITEM 4. CONTROLS AND PROCEDURES

Senior management of both Dominion Energy and Virginia Power, including Dominion Energy and Virginia Power’s CEO and CFO, evaluated the effectiveness of each company’s disclosure controls and procedures as of the end of the period covered by this report. Based on this evaluation process, each of Dominion Energy and Virginia Power’s CEO and CFO have concluded that each company’s disclosure controls and procedures are effective.

There were no changes that occurred during the last fiscal quarter that materially affected, or are reasonably likely to materially affect, Dominion Energy or Virginia Power’s internal control over financial reporting.

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PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, the Companies are parties to various legal, environmental or other regulatory proceedings, including in the ordinary course of business. SEC regulations require disclosure of certain environmental matters when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that the Companies reasonably believe will exceed a specified threshold. Pursuant to the SEC regulations, the Companies use a threshold of $1 million for such proceedings.

See the following for discussions on various legal, environmental and other regulatory proceedings to which the Companies are a party, which information is incorporated herein by reference:

•Notes 13 and 23 to the Consolidated Financial Statements and Future Issues and Other Matters in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025.

•Notes 12 and 16 to the Consolidated Financial Statements and Future Issues and Other Matters in MD&A in this report.

ITEM 1A. RISK FACTORS

The Companies’ businesses are influenced by many factors that are difficult to predict, involve risks and uncertainties that may materially affect actual results and are often beyond the Companies’ control. A number of these risks and uncertainties have been identified in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 and updated in the Companies’ Quarterly Report on Form 10-Q for the quarter ended June 30, 2026, which should be taken into consideration when reviewing the information contained in this report. There have been no material changes with regard to the risk factors previously disclosed in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2025 and in the Companies’ Quarterly Report on Form 10-Q for the quarter ended June 30, 2026. For other factors that may cause actual results to differ materially from those indicated in any forward-looking statement or projection contained in this report, see Forward-Looking Statements in MD&A in this report.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Dominion Energy

Purchases of Equity Securities

Period		Total Number of Shares (or Units) Purchased(1)				Average Price Paid per Share (or Unit)(2)				Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs				Maximum Number (or Approximate Dollar Value)  of Shares (or Units) that May Yet Be Purchased under the Plans or Programs(3)
7/1/26 - 7/31/26			485			$	67.79				—			$	0.92 billion
8/1/26 - 8/31/26			—				—				—				0.92 billion
9/1/26 - 9/30/26			992				66.38				—				0.92 billion
Total			1,477			$	66.84				—			$	0.92 billion

(1)Represents shares of common stock that were tendered by employees to satisfy tax withholding obligations on vested restricted stock.

(2)Represents the weighted-average price paid per share.

(3)In November 2020, the Dominion Energy Board of Directors authorized the repurchase of up to $1.0 billion of shares of common stock. This repurchase program has no expiration date or price or volume targets and may be modified, suspended or terminated at any time. Shares may be purchased through open market or privately negotiated transactions or otherwise at the discretion of management subject to prevailing market conditions, applicable securities laws and other factors.

ITEM 5. OTHER INFORMATION

During the last fiscal quarter, none of the Companies’ directors or officers (as defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.

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ITEM 6. EXHIBITS

Exhibit Number		Description		Dominion Energy		Virginia Power
2.1		Agreement and Plan of Merger, dated as of May 15, 2026, by and among NextEra Energy, Inc., WG Development Corp., CS Holdco, LLC and Dominion Energy, Inc. (Exhibit 2.1, Form 8-K filed May 18, 2026, File No. 1-8489).		X
3.1.a		Dominion Energy, Inc. Amended and Restated Articles of Incorporation, dated as of December 17, 2024 (Exhibit 3.1, Form 8-K filed December 17, 2024, File No.1-8489).		X
3.1.b		Virginia Electric and Power Company Amended and Restated Articles of Incorporation, as in effect on October 30, 2014 (Exhibit 3.1.b, Form 10-Q filed November 3, 2014, File No. 1-2255).				X
3.2.a		Dominion Energy, Inc. Bylaws, as amended and restated, effective June 26, 2025 (Exhibit 3.1, Form 8-K filed June 27, 2025, File No. 1-8489).		X
3.2.b		Virginia Electric and Power Company Amended and Restated Bylaws, effective June 1, 2009 (Exhibit 3.1, Form 8-K filed June 3, 2009, File No. 1-2255).				X
4		Dominion Energy, Inc. and Virginia Electric and Power Company agree to furnish to the Securities and Exchange Commission upon request any other instrument with respect to long-term debt as to which the total amount of securities authorized does not exceed 10% of any of their total consolidated assets.		X		X
4.1		Senior Indenture, dated as of September 1, 2017, between Virginia Electric and Power Company and U.S. Bank National Association, as Trustee (Exhibit 4.1, Form 8-K filed September 13, 2017, File No.000-55337); First Supplemental Indenture, dated as of September 1, 2017 (Exhibit 4.2, Form 8-K filed September 13, 2017, File No.000-55337); Second Supplemental Indenture, dated as of March 1, 2018 (Exhibit 4.2, Form 8-K filed March 22, 2018, File No. 000-55337); Third Supplemental Indenture, dated as of November 1, 2018 (Exhibit 4.2, Form 8-K filed November 28, 2018, File No. 000-55337); Fourth Supplemental Indenture, dated as of July 1, 2019 (Exhibit 4.2, Form 8-K filed July 10, 2019, File No. 00-55337); Fifth Supplemental Indenture, dated as of December 1, 2019 (Exhibit 4.2, Form 8-K filed December 5, 2019, File No. 000-55337); Sixth Supplemental Indenture, dated as of December 1, 2020 (Exhibit 4.2, Form 8-K filed December 15, 2020, File No. 00-55337); Seventh Supplemental Indenture, dated as of November 1, 2021 (Exhibit 4.2, Form 8-K filed November 22, 2021, File No.000-55337); Eighth Supplemental Indenture, dated as of November 1, 2021 (Exhibit 4.3, Form 8-K filed November 22, 2021, File No.000-55337); Ninth Supplemental Indenture, dated as of January 1, 2022 (Exhibit 4.3, Form 8-K filed January 13, 2022, File No.000-55337); Tenth Supplemental Indenture, dated as of May 1, 2022 (Exhibit 4.2, Form 8-K filed May 31, 2022, File No. 000-55337); Eleventh Supplemental Indenture, dated as of May 1, 2022 (Exhibit 4.3, Form 8-K filed May 31, 2022, File No. 000-55337); Twelfth Supplemental Indenture, dated as of March 1, 2023 (Exhibit 4.2. Form 8-K filed March 30, 2023, File No. 000-55337); Thirteenth Supplemental Indenture, dated as of March 1, 2023 (Exhibit 4.3. Form 8-K filed March 30, 2023, File No. 000-55337); Fourteenth Supplemental Indenture, dated as of August 1, 2023 (Exhibit 4.2. Form 8-K filed August 10, 2023, File No. 000-55337); Fifteenth Supplemental Indenture, dated as of August 1, 2023 (Exhibit 4.3. Form 8-K filed August 10, 2023, File No. 000-55337); Sixteenth Supplemental Indenture, dated as of January 1, 2024 (Exhibit 4.2. Form 8-K filed January 8, 2024, File No. 000-55337); Seventeenth Supplemental Indenture, dated as of January 1, 2024 (Exhibit 4.3. Form 8-K filed January 8, 2024, File No. 000-55337); Eighteenth Supplemental Indenture, dated as of August 1, 2024 (Exhibit 4.2, Form 8-K filed August 12, 2024, File No. 000-55337); Nineteenth Supplemental Indenture, dated as of August 1, 2024 (Exhibit 4.3, Form 8-K filed August 12, 2024, File No. 000-55337); Twentieth Supplemental Indenture, dated as of March 1, 2025 (Exhibit 4.2, Form 8-K filed March 3, 2025, File No. 000-55337); Twenty-First Supplemental Indenture, dated as of March 1, 2025 (Exhibit 4.3, Form 8-K filed March 3, 2025, File No. 000-55337); Twenty-Second Supplemental Indenture, dated as of September 1, 2025 (Exhibit 4.2, Form 8-K filed September 10, 2025, File No. 000-55337); Twenty-Third Supplemental Indenture, dated as of September 1, 2025 (Exhibit 4.3, Form 8-K filed September 10, 2025, File No. 000-55337); Twenty-Fourth Supplemental Indenture, dated as of March 1, 2026 (Exhibit 4.2, Form 8-K filed March 2, 2026, File No. 000-55337); Twenty-Fifth Supplemental Indenture, dated as of March 1, 2026 (Exhibit 4.3, Form 8-K filed March 2, 2026, File No. 000-55337); Twenty-Sixth Supplemental Indenture, dated as of August 1, 2026 (Exhibit 4.2, Form 8-K filed August 17, 2026, File No.		X		X

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Exhibit Number		Description		Dominion Energy		Virginia Power
		000-55337); Twenty-Seventh Supplemental Indenture, dated as of August 1, 2026 (Exhibit 4.3, Form 8-K filed August 17, 2026, File No. 000-55337).
31.a		Certification by Chief Executive Officer of Dominion Energy, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X
31.b		Certification by Chief Financial Officer of Dominion Energy, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X
31.c		Certification by Chief Executive Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).				X
31.d		Certification by Chief Financial Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).				X
32.a		Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion Energy, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).		X
32.b		Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Virginia Electric and Power Company as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).				X
99		Condensed consolidated earnings statements (filed herewith).		X		X
101		The following financial statements from Dominion Energy, Inc.’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2026, filed on October 30, 2026, formatted in iXBRL (Inline eXtensible Business Reporting Language): (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income (iii) Consolidated Balance Sheets, (iv) Consolidated Statements of Equity, (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements. The following financial statements from Virginia Electric and Power Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2026, filed on October 30, 2026, formatted in iXBRL (Inline eXtensible Business Reporting Language): (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income, (iii) Consolidated Balance Sheets, (iv) Consolidated Statements of Equity (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements.		X		X
104		Cover Page Interactive Data File formatted in iXBRL (Inline eXtensible Business Reporting Language) and contained in Exhibit 101.		X		X

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	DOMINION ENERGY, INC. Registrant
October 30, 2026	/s/ Gary G. Ratliff, Jr.
	Gary G. Ratliff, Jr. Vice President, Controller and Chief Accounting Officer
	VIRGINIA ELECTRIC AND POWER COMPANY Registrant
October 30, 2026	/s/ Gary G. Ratliff, Jr.
	Gary G. Ratliff, Jr. Vice President, Controller and Chief Accounting Officer

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