0000715957 d:VirginiaElectricAndPowerCompanyMember us-gaap:~~FixedIncomeSecuritiesMember~~CommodityContractMember d:~~GovernmentDebtSecuritiesMember us-gaap:FairValueMeasurementsRecurringMember 2019-12-31 0000715957 d:PowerPurchaseArrangementMember 2019-01-01 2019-06-30~~ElectricFuelAndOtherEnergyRelatedPurchasesMember 2020-01-01 2020-06-30

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 June 30, ~~2020~~2021

☐	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

~~001-37591~~	~~DOMINION ENERGY GAS HOLDINGS, LLC~~	~~46-3639580~~

	120 Tredegar Street Richmond, Virginia 23219 (804) 819-2000

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
	DRUA	2016 Series A 5.25% Enhanced Junior Subordinated Notes	New York Stock Exchange
	DCUE	2019 Series A Corporate Units	New York Stock Exchange
~~DOMINION ENERGY GAS~~ ~~HOLDINGS, LLC~~		~~2014 Series C 4.6% Senior Notes~~	~~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 ☐

~~Dominion Energy Gas Holdings, LLC 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 ☐

~~Dominion Energy Gas Holdings, LLC 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~~	☐

~~Dominion Energy Gas Holdings, LLC~~

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

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 ☒

~~Dominion Energy Gas Holdings, LLC Yes~~ ☐ No ☒

At July ~~17, 2020,~~30, 2021, the latest practicable date for determination, Dominion Energy, Inc. had ~~840,135,854~~808,487,324 shares of common stock outstanding and Virginia Electric and Power Company had 274,723 shares of common stock outstanding. Dominion Energy, Inc. is the sole holder of Virginia Electric and Power Company’s common stock. ~~Dominion Energy, Inc. holds all of the membership interests of Dominion Energy Gas Holdings, LLC.~~

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

VIRGINIA ELECTRIC AND POWER COMPANY ~~AND DOMINION ENERGY GAS HOLDINGS, LLC MEET~~MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION H(1)(a) AND (b) OF FORM 10-Q AND ~~ARE~~IS FILING THIS FORM 10-Q UNDER THE REDUCED DISCLOSURE FORMAT.

COMBINED INDEX

		Page Number
	Glossary of Terms	3

	PART I. Financial Information	9

Item 1.	Financial Statements	9
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	~~105~~78
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	~~124~~95
Item 4.	Controls and Procedures	~~125~~96

	PART II. Other Information	~~126~~

Item 1.	Legal Proceedings	~~126~~97
Item 1A.	Risk Factors	~~126~~97
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	~~126~~97
Item 5.	Other Information	97
Item 6.	Exhibits	~~128~~98

GLOSSARY OF TERMS

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

Abbreviation or Acronym		Definition
~~2016 Equity Units~~		Dominion Energy’s 2016 Series A Equity Units issued in August 2016, initially in the form of 2016 Series A Corporate Units, consisting of a stock purchase contract and a 1/40 interest in RSNs issued by Dominion Energy
2019 Equity Units		Dominion Energy’s 2019 Series A Equity Units issued in June 2019, initially in the form of 2019 Series A Corporate Units, consisting of a stock purchase contract and a 1/10 interest in a share of the Series A Preferred Stock
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
2021 Triennial Review		Virginia Commission review of Virginia Power’s earned return on base rate generation and distribution services for the four successive 12-month test periods beginning January 1, 2017 and ending December 31, 2020
ACE Rule		Affordable Clean Energy Rule
AFUDC		Allowance for funds used during construction
Align RNG		Align RNG, LLC, a joint venture between Dominion Energy and Smithfield Foods, Inc.
~~Altavista~~		~~Altavista biomass power station~~
~~AMI~~		~~Advanced Metering Infrastructure~~
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 ~~and constructed and operated by DETI~~
~~BACT~~		~~Best available control technology~~
bcf		Billion cubic feet
Birdseye		Birdseye Renewable Energy, LLC
Bear Garden		A 590 MW combined-cycle, natural gas-fired power station in Buckingham County, Virginia
BHE		The legal entity, Berkshire Hathaway Energy Company,
~~Blue Racer~~		~~Blue Racer~~ one or more of its consolidated subsidiaries (including Dominion Energy Gas, Dominion Energy Midstream ~~LLC, a joint venture between Caiman~~and Cove Point effective November 1, 2020), or the entirety of Berkshire Hathaway Energy ~~II, LLC~~Company and ~~FR BR Holdings, LLC~~
BP		~~BP Wind Energy North America Inc.~~its consolidated subsidiaries
Brookfield		Brookfield Super-Core Infrastructure Partners, an infrastructure fund managed by Brookfield Asset Management Inc.
Brunswick County		A 1,376 MW combined-cycle, natural gas-fired power station in Brunswick County, Virginia
CAA		Clean Air Act
~~CARES Act~~		~~Coronavirus Aid, Relief and Economic Security Act, enacted on March 27, 2020~~
CCR		Coal combustion residual
CCRO		Customer credit reinvestment offset
CEO		Chief Executive Officer
CEP		Capital Expenditure Program, as established by House Bill 95, Ohio legislation enacted in 2011, deployed by East Ohio to recover certain costs associated with capital investment
CERCLA		Comprehensive Environmental Response, Compensation and Liability Act of 1980, also known as Superfund
CFO		Chief Financial Officer
CO₂		Carbon dioxide

Colonial Trail West		A 142 MW utility-scale solar power station located in Surry County, Virginia
Companies		Dominion Energy and Virginia Power, ~~and Dominion Energy Gas,~~ collectively
Contracted ~~Generation~~Assets		Contracted ~~Generation~~Assets 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
~~Cove Point LNG Facility~~		~~An LNG import/export and storage facility, including the Liquefaction Facility, located on the Chesapeake Bay in Lusby, Maryland~~LP)
CPCN		Certificate of Public Convenience and Necessity
CWA		Clean Water Act
DCP		The legal entity, CPMLP Holding Company, LLC (formerly known as Dominion Cove Point, ~~LLC,~~LLC), one or more of its consolidated subsidiaries (including Dominion Energy Midstream), or the entirety of ~~Dominion Cove Point,~~ CPMLP Holding Company, LLC and its consolidated subsidiaries
~~DECG~~		~~Dominion Energy Carolina Gas Transmission, Inc.~~
DECGS		Carolina Gas Services, Inc. (formerly known as Dominion Energy Carolina Gas Services, Inc.)
DEQPS		Dominion Energy Questar Pipeline Services, Inc.
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
DETI		Eastern Gas Transmission and Storage, Inc. (formerly known as Dominion Energy Transmission, Inc.)
DGI		Dominion Generation, Inc.
DGP		Eastern Gathering and Processing, Inc. (formerly known as Dominion Gathering and Processing, Inc.)
DMLPHCII		Eastern MLP Holding Company II, LLC (formerly known as Dominion MLP Holding Company II, ~~LLC~~LLC)
DOE		U.S. Department of Energy
Dominion Energy		The legal entity, Dominion Energy, Inc., one or more of its consolidated subsidiaries (other than Virginia ~~Power and Dominion Energy Gas)~~Power) or operating segments, or the entirety of Dominion Energy, Inc. and its consolidated subsidiaries
Dominion Energy Gas		The legal entity, Eastern Energy Gas Holdings, LLC (formerly known as Dominion Energy Gas Holdings, ~~LLC,~~LLC), one or more of its consolidated subsidiaries ~~or operating segment,~~(consisting of DETI, DCP, DMLPHCII and Dominion Iroquois), or the entirety of ~~Dominion~~Eastern Energy Gas Holdings, LLC and its consolidated subsidiaries
Dominion Energy ~~Gas~~ ~~Restructuring~~		~~The acquisition of DCP and DMLPHCII from, and the disposition of East Ohio and DGP to, Dominion Energy by Dominion Energy Gas on November 6, 2019~~
~~Dominion Energy~~ Midstream		The legal entity, Northeast Midstream Partners, LP (formerly known as Dominion Energy Midstream Partners, ~~LP,~~LP), one or more of its consolidated subsidiaries, or the entirety of ~~Dominion Energy~~Northeast Midstream Partners, LP and its consolidated subsidiaries
Dominion Energy Questar Pipeline		The legal entity, Dominion Energy Questar Pipeline, LLC, one or more of its consolidated subsidiaries (including its 50% noncontrolling interest in White River Hub), or the entirety of Dominion Energy Questar Pipeline, LLC and its consolidated subsidiaries
Dominion Energy South Carolina		Dominion Energy South Carolina operating segment
Dominion Energy Virginia		Dominion Energy Virginia operating segment
Dominion Iroquois		The legal entity Iroquois, Inc. (formerly known as Dominion Iroquois, Inc.), one or more of its consolidated subsidiaries, or the entirety of Iroquois, Inc. and its consolidated subsidiaries, which held a 50% noncontrolling interest in Iroquois
DSM		Demand-side management
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

East Ohio		The East Ohio Gas Company, doing business as Dominion Energy Ohio
EnergySolutions		EnergySolutions, LLC

EPA		U.S. Environmental Protection Agency
EPS		Earnings per common share
~~Export Customers~~		~~ST Cove Point, LLC, a joint venture of Sumitomo Corporation and Tokyo Gas Co., LTD., and GAIL Global (USA) LNG, LLC~~
FERC		Federal Energy Regulatory Commission
FILOT		Fee in lieu of taxes
Four Brothers		Four Brothers Solar, LLC, a limited liability company owned by Dominion Energy and Four Brothers Holdings, LLC, a subsidiary of GIP
Fowler Ridge		Fowler I Holdings LLC, a wind-turbine facility ~~joint venture with BP~~ in Benton County, Indiana
FTRs		Financial transmission rights
GAAP		U.S. generally accepted accounting principles
~~Gal~~		~~Gallon~~
Gas Distribution		Gas Distribution ~~operating segment~~
~~Gas Transmission & Storage~~		~~Gas Transmission & Storage~~ operating segment
GENCO		South Carolina Generating Company, Inc.
GHG		Greenhouse gas
GIP		The legal entity, Global Infrastructure Partners, one or more of its consolidated subsidiaries, or the entirety of Global Infrastructure Partners and its consolidated subsidiaries
Granite Mountain		Granite Mountain Holdings, LLC, a limited liability company owned by Dominion Energy and Granite Mountain Renewables, LLC, a subsidiary of GIP
Grassfield Solar		A proposed 20 MW utility-scale solar power station located in Chesapeake, Virginia
Greensville County		A 1,588 MW combined-cycle, natural gas-fired power station in Greensville County, Virginia
GT&S Transaction		The sale by Dominion Energy to BHE of Dominion Energy Gas, DGP, DECGS, Eastern Energy Field Services, Inc. (formerly known as Dominion Energy Field Services, Inc.) and Modular LNG Holdings, Inc. (formerly known as Dominion Modular LNG Holdings, Inc.) (which holds a 50% noncontrolling interest in JAX LNG) pursuant to a purchase and sale agreement entered into on July 3, 2020, which was completed on November 1, 2020
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
Hope		Hope Gas, Inc., doing business as Dominion Energy West Virginia
~~Hopewell~~		~~Polyester biomass power station~~
Iron Springs		Iron Springs Holdings, LLC, a limited liability company owned by Dominion Energy and Iron Springs Renewables, LLC, a subsidiary of GIP
Iroquois		Iroquois Gas Transmission System, L.P.
ISO		Independent system operator
JAX LNG		JAX LNG, LLC, an LNG supplier in Florida serving the marine and LNG markets
~~June 2006 hybrids~~		~~Dominion Energy’s 2006 Series A Enhanced Junior Subordinated Notes due 2066~~
Kewaunee		Kewaunee nuclear power station
kV		Kilovolt
~~Liquefaction Facility~~LIBOR		~~A natural gas export/liquefaction facility at the Cove Point LNG Facility~~London Interbank Offered Rate
LNG		Liquefied natural gas
~~MATS~~		~~Utility Mercury and Air Toxics Standard Rule~~

MD&A		Management’s Discussion and Analysis of Financial Condition and Results of Operations
MGD		Million gallons a day
Millstone		Millstone nuclear power station
Millstone 2019 power purchase agreements		Power purchase agreements with Eversource Energy and The United Illuminating Company for Millstone to provide nine million MWh per year of electricity for ten years
MW		Megawatt

MWh		Megawatt hour
NAV		Net asset value
~~NGL~~		~~Natural gas liquid~~
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
Norge Solar		A proposed 20 MW utility-scale solar power station located in James City County, Virginia
North Anna		North Anna nuclear power station
North Carolina Commission		North Carolina Utilities Commission
NRC		U.S. Nuclear Regulatory Commission
~~NSPS~~		~~New Source Performance Standards~~
~~NWP 12~~		~~A nationwide permit from the Army Corps of Engineers authorizing activities required for the~~ ~~construction, maintenance, repair and removal of utility lines, including electric transmission, gas pipelines, water and communications conduit and associated facilities in waters of the U.S.~~
~~NYSE~~		~~New York Stock Exchange~~
~~Ohio Commission~~		~~Public Utilities Commission of Ohio~~
Order 1000		Order issued by FERC adopting requirements for electric transmission planning, cost allocation and development
~~Overthrust~~		~~Dominion Energy Overthrust Pipeline, L.L.C.~~
PIR		Pipeline Infrastructure Replacement program deployed by East Ohio
PJM		PJM Interconnection, ~~L.L.C.~~
~~Predecessor~~		~~Dominion Energy as the predecessor for accounting purposes for the period of Dominion Energy’s ownership of DCP and DMLPHCII until the completion of the Dominion Energy Gas Restructuring~~LLC
PREP		Pipeline Replacement and Expansion Program, a program of replacing, upgrading and expanding natural gas utility infrastructure deployed by Hope
PSD		Prevention of significant deterioration
PSNC		Public Service Company of North Carolina, Incorporated, doing business as Dominion Energy North Carolina
Q-Pipe Group		Collectively, Dominion Energy Questar Pipeline, DEQPS and QPC Holding Company, LLC (including its subsidiary Questar Southern Trails Pipeline Company)
Q-Pipe Transaction		A previously proposed sale by Dominion Energy to BHE of the Q-Pipe Group pursuant to a purchase and sale agreement entered into on October 5, 2020 and terminated on July 9, 2021
Questar Gas		Questar Gas Company, doing business as Dominion Energy Utah, Dominion Energy Wyoming and Dominion Energy Idaho
~~RCC~~Regulation Act		~~Replacement Capital Covenant~~Legislation effective July 1, 2007, that amended the Virginia Electric Utility Restructuring Act and fuel factor statute, which legislation is also known as the Virginia Electric Utility Regulation Act, as amended in 2015 and 2018
RGGI		Regional Greenhouse Gas Initiative
RICO		Racketeer Influenced and Corrupt Organizations Act
Rider B		A rate adjustment clause associated with the recovery of costs related to the conversion of three of Virginia Power’s coal-fired power stations to biomass
Rider BW		A rate adjustment clause associated with the recovery of costs related to Brunswick County
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 facilities in Virginia
Rider GV		A rate adjustment clause associated with the recovery of costs related to Greensville County

Rider R		A rate adjustment clause associated with the recovery of costs related to Bear Garden
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 S		A rate adjustment clause associated with the recovery of costs related to the Virginia City Hybrid Energy Center

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
Rider U		A rate adjustment clause associated with the recovery of costs of new underground distribution facilities
Rider US-2		A rate adjustment clause associated with the recovery of costs related to Woodland Solar, Scott Solar and Whitehouse Solar
Rider US-3		A rate adjustment clause associated with the recovery of costs related to Colonial Trail West and Spring Grove 1
Rider US-4		A rate adjustment clause associated with the recovery of costs related to Sadler Solar
Rider W		A rate adjustment clause associated with the recovery of costs related to Warren County
~~Riders C1A, C2A and~~ ~~C3A~~		~~Rate adjustment clauses associated with the recovery of cost related to certain DSM programs approved in DSM cases~~
ROE		Return on equity
~~RSN~~		~~Remarketable subordinated note~~
RTO		Regional transmission organization
Sadler Solar		~~An approximately~~A 100 MW ~~proposed~~ utility-scale solar power station located in Greensville County, Virginia
Santee Cooper		South Carolina Public Service Authority
SBL Holdco		SBL Holdco, LLC, a wholly-owned subsidiary of DGI
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
SCDHEC		South Carolina Department of Health and Environmental Control
SCDOR		South Carolina Department of Revenue
Scott Solar		A 17 MW utility-scale solar power station in Powhatan County, Virginia
SEC		U.S. Securities and Exchange Commission
~~SEMI~~		~~SCANA Energy Marketing, LLC (formerly known as SCANA Energy Marketing, Inc.), a subsidiary of~~ ~~SCANA~~ ~~through December 2019, and effective December 2019, a subsidiary of Wrangler~~
~~September 2006 hybrids~~		~~Dominion Energy’s 2006 Series B Enhanced Junior Subordinated Notes due 2066~~
Series A Preferred Stock		Dominion Energy’s 1.75% Series A Cumulative Perpetual Convertible Preferred Stock, without par value, with a liquidation preference of $1,000 per share
Series B Preferred Stock		Dominion Energy’s 4.65% Series B 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~~Spring Grove 1		~~Southampton biomass power station~~
~~Southern~~		~~The legal entity, The Southern Company, one or more of its consolidated subsidiaries, or the entirety of The Southern Company and its consolidated subsidiaries~~

~~Spring Grove 1~~		~~An approximately~~A 98 MW ~~proposed~~ utility-scale solar power station located in Surry County, Virginia
Standard & Poor’s		Standard & Poor’s Ratings Services, a division of S&P Global Inc.
Summer		V.C. Summer nuclear power station
Supply Header Project		A project previously intended for DETI to provide approximately 1,500,000 Dths of firm transportation service to various customers in connection with the Atlantic Coast Pipeline Project
Surry		Surry nuclear power station
Sycamore Solar		A proposed 42 MW utility-scale solar power station located in Pittsylvania County, Virginia
Terra Nova Renewable Partners		AThe legal entity, Terra Nova Renewable Partners, LLC, a partnership comprised primarily of institutional investors advised by J.P. Morgan Asset Management-Global Real Assets, or one or more of its consolidated subsidiaries
Three Cedars		Granite Mountain and Iron Springs, collectively
UEX Rider		Uncollectible Expense Rider deployed by East Ohio
Utah Commission		Utah Public Service Commission

VCEA		Virginia Clean Economy Act ~~passed by the Virginia General Assembly in~~of March 2020 ~~and enacted on April 11, 2020~~
~~VDEQ~~		~~Virginia Department of Environmental Quality~~
VEBA		Voluntary Employees’ Beneficiary Association
VIE		Variable interest entity
Virginia City Hybrid Energy Center		A 610 MW baseload carbon-capture compatible, clean coal powered electric generation facility in Wise County, Virginia
Virginia Commission		Virginia State Corporation Commission
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
~~VOC~~		~~Volatile organic compounds~~
Warren County		A 1,350 MW combined-cycle, natural gas-fired power station in Warren County, Virginia
WECTEC		WECTEC Global Project Services, Inc., a wholly-owned subsidiary of Westinghouse
~~West Virginia Commission~~		~~Public Service Commission of West Virginia~~
Westinghouse		Westinghouse Electric Company LLC
Wexpro		The legal entity, Wexpro Company, one or more of its consolidated subsidiaries, or the entirety of Wexpro Company and its consolidated subsidiaries
Whitehouse Solar		A 20 MW utility-scale solar power station in Louisa County, Virginia
White River Hub		White River Hub, LLC
Wisconsin Commission		Public Services Commission of Wisconsin
Woodland Solar		A 19 MW utility-scale solar power station in Isle of Wight County, Virginia
WP&L		Wisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation
WPSC		Wisconsin Public Service Corporation, a subsidiary of WEC Energy Group
Wrangler		Wrangler Retail Gas Holdings, LLC, a partnership between Dominion Energy and Interstate Gas Supply, Inc.
~~Wyoming Commission~~		~~Wyoming Public Service Commission~~

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,					Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019		2020			2019			2021			2020			2021		2020
(millions, except per share amounts)
Operating Revenue⁽¹⁾	$	3,585		$	3,970	$	8,081		$	7,828		$	3,038		$	3,106		$	6,908	$	7,044
Operating Expenses
Electric fuel and other energy-related purchases		505			718		1,173			1,509			487			507			1,037		1,164
Purchased electric capacity		11			24		13			63			25			11			36		13
Purchased gas		74			227		501			957			121			90			605		524
Other operations and maintenance		995			1,283		2,038			2,285			895			852			1,882		1,743
Depreciation, depletion and amortization		673			661		1,346			1,312			604			578			1,212		1,156
Other taxes		256			284		540			576			222			220			479		460
Impairment of assets and other charges		531			312		1,299			1,147			321			44			416		812
Total operating expenses		3,045			3,509		6,910			7,849			2,675			2,302			5,667		5,872
Income (loss) from operations		540			461		1,171			(21	)
Earnings (loss) from equity method investees		(2,281	)		39		(2,228	)		80
Income from operations													363			804			1,241		1,172
Earnings from equity method investees													65			2			145		5
Other income		502			53		50			400			312			498			599		41
Interest and related charges		449			452		939			921			518			398			571		830
Income (loss) from operations including noncontrolling interests before income tax expense (benefit)		(1,688	)		101		(1,946	)		(462	)
Income from continuing operations including noncontrolling interests before income tax expense (benefit)													222			906			1,414		388
Income tax expense (benefit)		(556	)		43		(575	)		157			(47	)		37			165		(13	)
Net Income From Continuing Operations Including Noncontrolling Interests													269			869			1,249		401
Net Income (Loss) From Discontinued Operations Including Noncontrolling Interests⁽¹⁾⁽²⁾													26			(2,001	)		54		(1,772	)
Net Income (Loss) Including Noncontrolling Interests		(1,132	)		58		(1,371	)		(619	)		295			(1,132	)		1,303		(1,371	)
Noncontrolling Interests		37			4		68			7			10			37			10		68
Net Income (Loss) Attributable to Dominion Energy	$	(1,169	)	$	54	$	(1,439	)	$	(626	)	$	285		$	(1,169	)	$	1,293	$	(1,439	)
Earnings Per Common Share
Net Income (Loss) attributable to Dominion Energy - Basic	$	(1.41	)	$	0.07	$	(1.75	)	$	(0.78	)
Net Income (Loss) attributable to Dominion Energy - Diluted		(1.41	)		0.05		(1.75	)		(0.78	)
Amounts attributable to Dominion Energy
Net Income from continuing operations												$	259		$	863		$	1,239	$	397
Net Income (Loss) from discontinued operations													26			(2,032	)		54		(1,836	)
Net Income (Loss) attributable to Dominion Energy												$	285		$	(1,169	)	$	1,293	$	(1,439	)
EPS - Basic
Net income from continuing operations												$	0.30		$	1.01		$	1.49	$	0.43
Net income (loss) from discontinued operations													0.03			(2.42	)		0.07		(2.18	)
Net income (loss) attributable to Dominion Energy												$	0.33		$	(1.41	)	$	1.56	$	(1.75	)
EPS - Diluted
Net income from continuing operations												$	0.30		$	0.90		$	1.49	$	0.35
Net income (loss) from discontinued operations													0.03			(2.42	)		0.07		(2.18	)
Net income (loss) attributable to Dominion Energy												$	0.33		$	(1.52	)	$	1.56	$	(1.83	)

(1)	See Note 10 for amounts attributable to related parties.

(2)	Includes income tax expense (benefit) of $4 million and $(593) million for the three months ended June 30, 2021 and 2020, respectively, and $11 million and $(562) million for the six months ended June 30, 2021 and 2020, respectively.

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

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Net income (loss) including noncontrolling interests	$	(1,132	)	$	58		$	(1,371	)	$	(619	)	$	295		$	(1,132	)	$	1,303		$	(1,371	)
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		2			(78	)		(264	)		(102	)		(16	)		2			23			(264	)
Changes in unrealized net gains (losses) on investment securities⁽²⁾		19			13			28			29			12			19			(19	)		28
Changes in net unrecognized pension and other postretirement benefit costs⁽³⁾		(1	)		113			(1	)		113			0			(1	)		6			(1	)
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities⁽⁴⁾		5			(21	)		27			(52	)		12			5			25			27
Net realized (gains) losses on investment securities⁽⁵⁾		(5	)		(1	)		(14	)		(1	)		(3	)		(5	)		(2	)		(14	)
Net pension and other postretirement benefit costs⁽⁶⁾		18			22			37			30			26			18			44			37
Total other comprehensive income (loss)		38			48			(187	)		17			31			38			77			(187	)
Comprehensive income (loss) including noncontrolling interests		(1,094	)		106			(1,558	)		(602	)		326			(1,094	)		1,380			(1,558	)
Comprehensive income attributable to noncontrolling interests		37			4			68			7			10			37			10			68
Comprehensive income (loss) attributable to Dominion Energy	$	(1,131	)	$	102		$	(1,626	)	$	(609	)	$	316		$	(1,131	)	$	1,370		$	(1,626	)

(1)	Net of ~~$(4)~~$5 million and ~~$27~~$(4) million tax for the three months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively, and net of ~~$89~~$(8) million and ~~$32~~$89 million tax for the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively.

(2)	Net of ~~$(6)~~$(2) million and ~~$(5)~~$(6) million tax for the three months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively, and net of ~~$(10)~~$8 million and ~~$(11)~~$(10) million tax for the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively.

(3)	Net of $(3) million and $3 million tax for the three months ended June 30, 2021 and 2020, respectively, and net of $(7) million and $3 million tax for the six months ended June 30, 2021 and 2020, respectively.

(4)	Net of $(4) million and $(2) million tax for the three months ended June 30, 2021 and 2020, respectively, and net of $(8) million and $(9) million tax for the six months ended June 30, 2021 and 2020, respectively.

(5)	Net of $1 million and $0 million tax for the three months ended June 30, 2021 and 2020, respectively, and net of $1 million and $4 million tax for the six months ended June 30, 2021 and 2020, respectively.

(6)	Net of $(9) million and $(8) million tax for the three months ended June 30, 2021 and 2020, respectively, and net of $(16) million and $(13) million tax for the six months ended June 30, 2021 and 2020, respectively.

~~(3)~~ Net of $3 million and $(49) million tax for the three months ended June 30, 2020 and 2019, respectively, and net of $3 million and $(49) million tax for the six months ended June 30, 2020 and 2019 respectively.

~~(4)~~Net of $(2) million and $8 million tax for the three months ended June 30, 2020 and 2019, respectively, and net of $(9) million and $18 million tax for the six months ended June 30, 2020 and 2019, respectively.

~~(5)~~Net of $— million and $— million tax for the three months ended June 30, 2020 and 2019, respectively, and net of $4 million and $— million tax for the six months ended June 30, 2020 and 2019, respectively.

~~(6)~~Net of $(8) million and $3 million tax for the three months ended June 30, 2020 and 2019 respectively, and net of $(13) million and $(11) million tax for the six months ended June 30, 2020 and 2019, respectively.

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

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2020			December 31, 2019⁽¹⁾			June 30, 2021			December 31, 2020⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	675		$	166		$	240		$	172
Customer receivables (less allowance for doubtful accounts of $44 and $20)		2,040			2,278
Other receivables (less allowance for doubtful accounts of $3 at both dates)⁽²⁾		233			367
Customer receivables (less allowance for doubtful accounts of $38 and $42)								1,728			2,295
Other receivables (less allowance for doubtful accounts of $4 and $3)								247			212
Inventories		1,735			1,742			1,538			1,550
Prepayments		589			328			450			309
Regulatory assets		616			879			873			699
Other		236			328			340			167
Current assets held for sale								1,507			1,482
Total current assets		6,124			6,088			6,923			6,886
Investments
Nuclear decommissioning trust funds		6,018			6,192			7,521			6,900
Investment in equity method affiliates		584			1,646			2,951			2,934
Other		382			379			384			404
Total investments		6,984			8,217			10,856			10,238
Property, Plant and Equipment
Property, plant and equipment		96,527			97,466			85,293			82,959
Accumulated depreciation, depletion and amortization		(28,547	)		(28,384	)		(26,067	)		(25,111	)
Total property, plant and equipment, net		67,980			69,082			59,226			57,848
Deferred Charges and Other Assets
Goodwill		8,946			8,946			7,405			7,381
Regulatory assets		9,438			7,687			8,763			9,133
Other		4,256			3,803			4,790			4,419
Total deferred charges and other assets		22,640			20,436			20,958			20,933
Total assets	$	103,728		$	103,823		$	97,963		$	95,905

(1)	Dominion Energy’s Consolidated Balance Sheet at December 31, ~~2019~~2020 has been derived from the audited Consolidated Balance Sheet at that date.

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

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30, 2021			December 31, 2020⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	2,096		$	1,937
Supplemental 364-Day credit facility borrowings		—			225
Short-term debt		3,028			895
Accounts payable		774			944
Accrued interest, payroll and taxes		997			1,133
Regulatory liabilities		631			809
Liability to Atlantic Coast Pipeline		115			1,052
Q-Pipe Transaction deposit		1,290			1,290
Other⁽²⁾		2,114			1,933
Current liabilities held for sale		631			625
Total current liabilities		11,676			10,843
Long-Term Debt
Long-term debt		31,288			30,915
Junior subordinated notes		2,162			2,161
Supplemental credit facility borrowings		250			—
Other		885			881
Total long-term debt		34,585			33,957
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		6,261			5,953
Regulatory liabilities		10,292			10,187
Other		8,265			8,504
Total deferred credits and other liabilities		24,818			24,644
Total liabilities		71,079			69,444
Commitments and Contingencies (see Note 17)
Equity
Preferred stock (See Note 16)		2,387			2,387
Common stock – no par⁽³⁾		21,369			21,258
Retained earnings		4,434			4,189
Accumulated other comprehensive loss		(1,640	)		(1,717	)
Total shareholders' equity		26,550			26,117
Noncontrolling interests		334			344
Total equity		26,884			26,461
Total liabilities and equity	$	97,963		$	95,905

(1)	Dominion Energy’s Consolidated Balance Sheet at December 31, 2020 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 10 for amounts attributable to related parties.

(3)	1.8 billion shares authorized; 807 million and 806 million shares outstanding at June 30, 2021 and December 31, 2020, respectively.

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

~~DOMINION ENERGY, INC.~~12

~~CONSOLIDATED BALANCE SHEETS—(Continued)~~

~~(Unaudited)~~

June 30, 2020

December 31, 2019⁽¹⁾

(millions)

LIABILITIES AND EQUITY

Current Liabilities

Securities due within one year

$
2,799

$
3,162

Supplemental 364-Day credit facility borrowings

225

—

Short-term debt

386

911

Accounts payable

797

1,115

Accrued interest, payroll and taxes

1,011

1,323

Regulatory liabilities

749

497

Reserves for SCANA legal proceedings

538

696

Derivative liabilities

586

408

Other⁽²⁾

2,446

1,827

Total current liabilities

9,537

9,939

Long-Term Debt

Long-term debt

33,844

30,313

Junior subordinated notes

2,858

3,406

Other

444

105

Total long-term debt

37,146

33,824

Deferred Credits and Other Liabilities

Deferred income taxes and investment tax credits

5,921

6,277

Regulatory liabilities

10,680

11,001

Derivative liabilities

748

332

Other⁽²⁾

8,812

8,417

Total deferred credits and other liabilities

26,161

26,027

Total liabilities

72,844

69,790

Commitments and Contingencies (see Note 17)

Equity

Preferred stock (See Note 16)

2,387

2,387

Common stock – no par⁽³⁾

23,984

23,824

Retained earnings

4,480

7,576

Accumulated other comprehensive loss

(1,980
)

(1,793
)
Total shareholders' equity

28,871

31,994

Noncontrolling interests

2,013

2,039

Total equity

30,884

34,033

Total liabilities and equity

$
103,728

$
103,823

~~(1) Dominion Energy’s Consolidated Balance Sheet at December 31, 2019 has been derived from the audited Consolidated Balance Sheet at that date.~~

~~(2) See Note 10 for amounts attributable to related parties.~~

~~(3) 1.8 billion shares authorized; 840 million shares and 838 million shares outstanding at June 30, 2020 and December 31, 2019, respectively.~~

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

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY ~~- QUARTER-TO-DATE~~

(Unaudited)

QUARTER-TO-DATE

	Preferred Stock				Common Stock					Dominion Energy Shareholders						Total									Preferred Stock				Common Stock					Dominion Energy Shareholders						Total
	Shares		Amount		Shares		Amount			Retained Earnings			AOCI			Shareholders' Equity			Noncontrolling Interests			Total Equity			Shares		Amount		Shares		Amount			Retained Earnings			AOCI			Shareholders' Equity			Noncontrolling Interests			Total Equity
(millions, except per share amounts)
March 31, 2019		—	$	—		802	$	20,834		$	7,806		$	(1,731	)	$	26,909		$	690		$	27,599
Net income including noncontrolling interests											54						54			4			58
Issuance of stock		2		1,596		1		78									1,674						1,674
Stock purchase contract component of 2019 Equity Units⁽¹⁾								(264	)								(264	)					(264	)
Stock awards (net of change in unearned compensation)								12									12						12
Dividends ($0.9175 per common share) and distributions											(736	)					(736	)		(10	)		(746	)
Other comprehensive income, net of tax														48			48						48
June 30, 2019		2	$	1,596		803	$	20,660		$	7,124		$	(1,683	)	$	27,697		$	684		$	28,381


March 31, 2020		2	$	2,387		839	$	23,902		$	6,455		$	(2,018	)	$	30,726		$	2,026		$	32,752			2	$	2,387		839	$	23,902		$	6,455		$	(2,018	)	$	30,726		$	2,026		$	32,752
Net income (loss) including noncontrolling interests											(1,169	)					(1,169	)		37			(1,132	)											(1,169	)					(1,169	)		37			(1,132	)
Issuance of stock						1		70									70						70							1		70									70						70
Stock awards (net of change in unearned compensation)								13									13						13									13									13						13
Preferred stock dividends⁽¹⁾											(16	)					(16	)					(16	)
Preferred stock dividends (See Note 16)																																			(16	)					(16	)					(16	)
Common stock dividends ($0.940 per share) and distributions											(789	)					(789	)		(50	)		(839	)											(789	)					(789	)		(50	)		(839	)
Other comprehensive income, net of tax														38			38						38															38			38						38
Other								(1	)		(1	)					(2	)					(2	)								(1	)		(1	)					(2	)					(2	)
June 30, 2020		2	$	2,387		840	$	23,984		$	4,480		$	(1,980	)	$	28,871		$	2,013		$	30,884			2	$	2,387		840	$	23,984		$	4,480		$	(1,980	)	$	28,871		$	2,013		$	30,884


March 31, 2021																										2	$	2,387		806	$	21,310		$	4,673		$	(1,671	)	$	26,699		$	339		$	27,038
Net income including noncontrolling interests																																			285						285			10			295
Issuance of stock																														1		49									49						49
Stock awards (net of change in unearned compensation)																																11									11						11
Preferred stock dividends (See Note 16)																																			(16	)					(16	)					(16	)
Common stock dividends ($0.630 per share) and distributions																																			(508	)					(508	)		(15	)		(523	)
Other comprehensive income, net of tax																																						31			31						31
Other																																(1	)								(1	)					(1	)
June 30, 2021																										2	$	2,387		807	$	21,369		$	4,434		$	(1,640	)	$	26,550		$	334		$	26,884

~~(1) See Note 16 for further information.~~

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

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY ~~- YEAR-TO-DATE~~

(Unaudited)

Preferred Stock

Common Stock

Dominion Energy Shareholders

Total

Shares

Amount

Shares

Amount

Retained Earnings

AOCI

Shareholders'
Equity

Noncontrolling
Interests

Total
Equity

(millions, except per share amounts)

��

December 31, 2018

—

$
—

681

$
12,588

$
9,219

$
(1,700
)

$
20,107

$
1,941

$
22,048

Net income (loss) including noncontrolling interests

(626
)

(626
)

7

(619
)
Issuance of stock

2

1,596

4

325

1,921

1,921

Stock purchase contract component of 2019 Equity Units⁽¹⁾

(264
)

(264
)

(264
)
Acquisition of SCANA

96

6,818

6,818

6,818

Acquisition of public interest in Dominion Energy Midstream

22

1,181

1,181

(1,221
)

(40
)
Stock awards (net of change in unearned compensation)

12

12

12

Dividends ($1.835 per common share) and distributions

(1,469
)

(1,469
)

(43
)

(1,512
)
Other comprehensive income, net of tax

17

17

17

June 30, 2019

2

$
1,596

803

$
20,660

$
7,124

$
(1,683
)

$
27,697

$
684

$
28,381

December 31, 2019

2

$
2,387

838

$
23,824

$
7,576

$
(1,793
)

$
31,994

$
2,039

$
34,033

Cumulative-effect of changes in accounting principles

(48
)

(48
)

(48
)
Net income (loss) including noncontrolling interests

(1,439
)

(1,439
)

68

(1,371
)
Issuance of stock

2

148

148

148

Stock awards (net of change in unearned compensation)

13

13

13

Preferred stock dividends⁽¹⁾

(32
)

(32
)

(32
)
Common stock dividends ($1.880 per share) and distributions

(1,577
)

(1,577
)

(94
)

(1,671
)
Other comprehensive loss, net of tax

(187
)

(187
)

(187
)
Other

(1
)

(1
)

(1
)
June 30, 2020

2

$
2,387

840

$
23,984

$
4,480

$
(1,980
)

$
28,871

$
2,013

$
30,884

YEAR-TO-DATE

~~1) See Note 16 for further information.~~

	Preferred Stock				Common Stock					Dominion Energy Shareholders						Total
	Shares		Amount		Shares		Amount			Retained Earnings			AOCI			Shareholders' Equity			Noncontrolling Interests			Total Equity
(millions, except per share amounts)
December 31, 2019		2	$	2,387		838	$	23,824		$	7,576		$	(1,793	)	$	31,994		$	2,039		$	34,033
Cumulative-effect of changes in accounting principles										$	(48	)					(48	)					(48	)
Net income (loss) including noncontrolling interests											(1,439	)					(1,439	)		68			(1,371	)
Issuance of stock						2		148									148						148
Stock awards (net of change in unearned compensation)								13									13						13
Preferred stock dividends (See Note 16)											(32	)					(32	)					(32	)
Common stock dividends ($1.880 per common share) and distributions											(1,577	)					(1,577	)		(94	)		(1,671	)
Other comprehensive loss, net of tax														(187	)		(187	)					(187	)
Other								(1	)								(1	)					(1	)
June 30, 2020		2	$	2,387		840	$	23,984		$	4,480		$	(1,980	)	$	28,871		$	2,013		$	30,884


December 31, 2020		2	$	2,387		806	$	21,258		$	4,189		$	(1,717	)	$	26,117		$	344		$	26,461
Net income including noncontrolling interests											1,293						1,293			10			1,303
Issuance of stock						1		97									97						97
Stock awards (net of change in unearned compensation)								15									15						15
Preferred stock dividends (See Note 16)											(32	)					(32	)					(32	)
Common stock dividends ($1.260 per share) and distributions											(1,016	)					(1,016	)		(20	)		(1,036	)
Other comprehensive income, net of tax														77			77						77
Other								(1	)								(1	)					(1	)
June 30, 2021		2	$	2,387		807	$	21,369		$	4,434		$	(1,640	)	$	26,550		$	334		$	26,884

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

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,

2020

2019

(millions)

Operating Activities

Net loss including noncontrolling interests

$
(1,371
)

$
(619
)
Adjustments to reconcile net loss including noncontrolling interests to net cash
provided by operating activities:

Depreciation, depletion and amortization (including nuclear fuel)

1,497

1,472

Deferred income taxes and investment tax credits

(231
)

107

Provision for refunds and rate credits to electric utility customers

—

953

Impairment of assets and other charges

1,297

1,012

Loss for equity method investee

2,315

—

Charge related to a voluntary retirement program

—

409

Net losses (gains) on nuclear decommissioning trust funds and other investments

117

(371
)
Revision to future ash pond and landfill closure costs

—

(113
)
Other adjustments

4

4

Changes in:

Accounts receivable

396

492

Inventories

7

(14
)
Deferred fuel and purchased gas costs, net

237

120

Prepayments

(193
)

22

Accounts payable

(191
)

(446
)
Accrued interest, payroll and taxes

(313
)

(264
)
Customer deposits

(7
)

(85
)
Margin deposit assets and liabilities

19

113

Other operating assets and liabilities

(447
)

(479
)
Net cash provided by operating activities

3,136

2,313

Investing Activities

Plant construction and other property additions (including nuclear fuel)

(2,915
)

(2,112
)
Cash and restricted cash acquired in the SCANA Combination

—

389

Acquisition of solar development projects

(187
)

(152
)
Proceeds from sales of securities

1,660

882

Purchases of securities

(1,710
)

(888
)
Proceeds from sales of assets and equity method investments

—

196

Contributions to equity method affiliates

(39
)

(132
)
Acquisition of equity method investments

(178
)

—

Other

35

(16
)
Net cash used in investing activities

(3,334
)

(1,833
)
Financing Activities

Issuance (repayment) of short-term debt, net

(525
)

2,040

Issuance of short-term notes

1,125

—

Repayment of short-term notes

(625
)

—

Supplemental 364-Day credit facility borrowings

225

—

Repayment of credit facility borrowings

—

(113
)
Issuance of long-term debt

4,355

798

Repayment of long-term debt, including redemption premiums

(2,210
)

(3,378
)
Issuance of 2019 Equity Units

—

1,582

Issuance of common stock

148

325

Common dividend payments

(1,577
)

(1,469
)
Other

(245
)

(96
)
Net cash provided by (used in) financing activities

671

(311
)
Increase in cash, restricted cash and equivalents

473

169

Cash, restricted cash and equivalents at beginning of period

269

391

Cash, restricted cash and equivalents at end of period

$
742

$
560

Supplemental Cash Flow Information

Significant noncash investing and financing activities:⁽¹⁾⁽²⁾

Accrued capital expenditures

$
346

$
311

Leases⁽³⁾

35

24

~~(1)~~

~~See Note 3 for noncash investing and financing activities related to the SCANA Combination.~~

~~(2)~~

See Note 16 for noncash financing activities related to derivative restructuring, the acquisition of the public interest in Dominion Energy Midstream and the issuance of stock purchase contracts associated with the 2019 Equity Units. See Note 18 to the Consolidated Financial Statements in Dominion Energy’s Annual Report on Form 10-K for the year ended December 31, 2019 for non-cash financing activities related to the remarketing of RSNs.

Six Months Ended June 30,	2021			2020
(millions)
Operating Activities
Net income (loss) including noncontrolling interests	$	1,303		$	(1,371	)
Adjustments to reconcile net income (loss) including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)		1,358			1,497
Deferred income taxes and investment tax credits		211			(231	)
Impairment of assets and other charges		416			1,297
Loss from investment in Atlantic Coast Pipeline		22			2,315
Net losses (gains) on nuclear decommissioning trust funds and other investments		(364	)		117
Other adjustments		232			40
Changes in:
Accounts receivable		337			360
Inventories		10			7
Deferred fuel and purchased gas costs, net		(300	)		237
Prepayments		(143	)		(193	)
Accounts payable		(42	)		(191	)
Accrued interest, payroll and taxes		(135	)		(313	)
Customer deposits		(15	)		(7	)
Margin deposit assets and liabilities		(176	)		19
Net realized and unrealized changes related to derivative activities		119			84
Pension and other postretirement benefits		(150	)		(105	)
Other operating assets and liabilities		(443	)		(426	)
Net cash provided by operating activities		2,240			3,136
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(2,664	)		(2,915	)
Acquisition of solar development projects		(36	)		(187	)
Proceeds from sales of securities		2,710			1,660
Purchases of securities		(2,683	)		(1,710	)
Contributions to equity method affiliates		(983	)		(39	)
Acquisition of equity method investments		0			(178	)
Other		(112	)		35
Net cash used in investing activities		(3,768	)		(3,334	)
Financing Activities
Issuance (repayment) of short-term debt, net		2,133			(525	)
Issuance of short-term notes		0			1,125
Repayment of short-term notes		0			(625	)
Supplemental 364-Day credit facility borrowings		0			225
Repayment of supplemental 364-day credit facility borrowings		(225	)		0
Issuance of long-term debt		1,250			4,355
Repayment of long-term debt, including redemption premiums		(722	)		(2,210	)
Supplemental credit facility borrowings		250			0
Issuance of common stock		97			148
Common dividend payments		(1,016	)		(1,577	)
Other		(182	)		(245	)
Net cash provided by financing activities		1,585			671
Increase in cash, restricted cash and equivalents		57			473
Cash, restricted cash and equivalents at beginning of period		247			269
Cash, restricted cash and equivalents at end of period	$	304		$	742

~~(3) Includes $32 million and $22 million~~

See Note 2 for disclosure of ~~financing leases at June 30, 2020 and 2019, respectively, and $3 million and $2 million of operating leases at June 30, 2020 and 2019, respectively.~~supplemental cash flow information.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,					Six Months Ended June 30,					Three Months Ended June 30,					Six Months Ended June 30,
	2020			2019		2020			2019		2021		2020			2021			2020
(millions)
Operating Revenue⁽¹⁾	$	1,805		$	1,938	$	3,735		$	3,903	$	1,741	$	1,805		$	3,571		$	3,735
Operating Expenses
Electric fuel and other energy-related purchases⁽¹⁾		366			536		858			1,132		349		366			755			858
Purchased (excess) electric capacity		(8	)		13		(17	)		46		4		(8	)		1			(17	)
Other operations and maintenance:
Affiliated suppliers		80			127		167			213		78		80			165			167
Other		296			438		627			631		321		296			747			627
Depreciation and amortization		307			299		618			603		323		307			647			618
Other taxes		85			90		172			175		83		85			176			172
Impairment of assets and other charges		44			197		808			743
Impairment of assets and other charges (benefit)												12		44			(39	)		808
Total operating expenses		1,170			1,700		3,233			3,543		1,170		1,170			2,452			3,233
Income from operations		635			238		502			360		571		635			1,119			502
Other income		52			16		—			53		40		52			72			—
Interest and related charges⁽¹⁾		137			135		263			270		128		137			264			263
Income before income tax expense		550			119		239			143		483		550			927			239
Income tax expense		60			19		29			23		69		60			139			29
Net Income	$	490		$	100	$	210		$	120	$	414	$	490		$	788		$	210

(1)	See Note 19 for amounts attributable to affiliates.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Net income	$	490		$	100		$	210		$	120		$	414		$	490		$	788		$	210
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		1			(11	)		(44	)		(18	)		(12	)		1			20			(44	)
Changes in unrealized net gains (losses) on nuclear decommissioning trust funds⁽²⁾		6			2			4			4			3			6			(2	)		4
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities⁽³⁾		—			1			—			1			0			0			1			0
Net realized (gains) losses on nuclear decommissioning trust funds⁽⁴⁾		(2	)		(1	)		(1	)		(1	)		(1	)		(2	)		0			(1	)
Total other comprehensive income (loss)		5			(9	)		(41	)		(14	)		(10	)		5			19			(41	)
Comprehensive income	$	495		$	91		$	169		$	106		$	404		$	495		$	807		$	169

(1)	Net of ~~$(1)~~$5 million and $4$(1) million tax for the three months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively, and net of ~~$15~~$(6) million and $6$15 million tax for the six months ended June 30, 2021 and 2020, ~~and 2019,~~ respectively.

(2)	Net of ~~$(1)~~$0 million and $—$(1) million tax for the three months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively, and net of ~~$(1)~~$0 million and $(1) million tax for the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively.

(3)	Net of~~$(1)~~ $0 million and ~~$ —~~$(1) million tax for the three months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively, and net of ~~$ (1)~~$0 million and ~~$ —~~$(1) million tax for the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively.

(4)	Net of $2$0 million and ~~$ —~~$2 million tax for the three months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively and net of $1$0 million and ~~$ —~~$1 million tax for the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2021			December 31, 2020⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	49		$	35
Customer receivables (less allowance for doubtful accounts of $22 and $23)		1,019			1,315
Other receivables (less allowance for doubtful accounts of $2 at both dates)		77			91
Affiliated receivables		198			5
Inventories (average cost method)		837			862
Regulatory assets		462			295
Other⁽²⁾		108			59
Total current assets		2,750			2,662
Investments
Nuclear decommissioning trust funds		3,511			3,197
Other		4			3
Total investments		3,515			3,200
Property, Plant and Equipment
Property, plant and equipment		48,212			46,736
Accumulated depreciation and amortization		(14,717	)		(14,167	)
Total property, plant and equipment, net		33,495			32,569
Deferred Charges and Other Assets
Regulatory assets		3,454			3,509
Other⁽²⁾		1,942			1,714
Total deferred charges and other assets		5,396			5,223
Total assets	$	45,156		$	43,654

June 30, 2020

December 31, 2019⁽¹⁾

(millions)

ASSETS

Current Assets

Cash and cash equivalents

$
37

$
17

Customer receivables (less allowance for doubtful accounts of $20 and $9)

1,184

1,163

Other receivables (less allowance for doubtful accounts of $2 at both dates)

94

106

Affiliated receivables

2

27

Inventories (average cost method)

874

873

Regulatory assets

197

433

Other⁽²⁾

64

57

Total current assets

2,452

2,676

Investments

Nuclear decommissioning trust funds

2,782

2,881

Other

3

3

Total investments

2,785

2,884

Property, Plant and Equipment

Property, plant and equipment

45,273

47,038

Accumulated depreciation and amortization

(13,774
)

(14,156
)
Total property, plant and equipment, net

31,499

32,882

Deferred Charges and Other Assets

Regulatory assets

3,780

1,863

Other⁽²⁾

1,524

1,123

Total deferred charges and other assets

5,304

2,986

Total assets

$
42,040

$
41,428

(1)	Virginia Power’s Consolidated Balance Sheet at December 31, ~~2019~~2020 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 19 for amounts attributable to affiliates.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30, 2020			December 31, 2019⁽¹⁾			June 30, 2021			December 31, 2020⁽¹⁾
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	7		$	4		$	461		$	8
Short-term debt		—			243			814			45
Accounts payable		305			334			311			332
Payables to affiliates		406			210			250			266
Affiliated current borrowings		340			107			348			380
Accrued interest, payroll and taxes		276			253			297			253
Asset retirement obligations		91			340
Regulatory liabilities		296			167			254			425
Derivative liabilities⁽²⁾		478			243			296			390
Other		598			571			715			728
Total current liabilities		2,797			2,472			3,746			2,827
Long-Term Debt
Long-term debt		12,328			12,325			12,760			13,207
Finance leases		30			16
Other								492			480
Total long-term debt		12,358			12,341			13,252			13,687
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,739			2,962			3,027			2,779
Asset retirement obligations		3,548			3,241			3,691			3,654
Regulatory liabilities		4,954			5,074			5,552			5,338
Other⁽²⁾		1,700			1,349			824			812
Total deferred credits and other liabilities		12,941			12,626			13,094			12,583
Total liabilities		28,096			27,439			30,092			29,097
Commitments and Contingencies (see Note 17)
Common Shareholder’s Equity
Common stock – no par⁽³⁾		5,738			5,738			5,738			5,738
Other paid-in capital		1,113			1,113			1,113			1,113
Retained earnings		7,163			7,167			8,246			7,758
Accumulated other comprehensive loss		(70	)		(29	)		(33	)		(52	)
Total common shareholder’s equity		13,944			13,989			15,064			14,557
Total liabilities and shareholder’s equity	$	42,040		$	41,428		$	45,156		$	43,654

(1)	Virginia Power’s Consolidated Balance Sheet at December 31, ~~2019~~2020 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 19 for amounts attributable to affiliates.

(3)	500,000 shares authorized; 274,723 shares outstanding at June 30, ~~2020~~2021 and December 31, ~~2019.~~2020.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER’S EQUITY

(Unaudited)

QUARTER-TO-DATE

Common Stock

Shares

Amount

Other Paid-In Capital

Retained Earnings

AOCI

Total

(millions, except for shares)

(thousands)

March 31, 2019

275

$
5,738

$
1,113

$
6,110

$
(17
)

$
12,944

Net income

100

100

Dividends

(71
)

(71
)
Other comprehensive loss, net of tax

(9
)

(9
)
June 30, 2019

275

$
5,738

$
1,113

$
6,139

$
(26
)

$
12,964

March 31, 2020

275

$
5,738

$
1,113

$
6,780

$
(75
)

$
13,556

Net income

490

490

Dividends

(107
)

(107
)
Other comprehensive income, net of tax

5

5

June 30, 2020

275

$
5,738

$
1,113

$
7,163

$
(70
)

$
13,944

	Common Stock
	Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total
(millions, except for shares)	(thousands)
March 31, 2020		275	$	5,738	$	1,113	$	6,780		$	(75	)	$	13,556
Net income								490						490
Dividends								(107	)					(107	)
Other comprehensive income, net of tax											5			5
June 30, 2020		275	$	5,738	$	1,113	$	7,163		$	(70	)	$	13,944

March 31, 2021		275	$	5,738	$	1,113	$	7,983		$	(23	)	$	14,811
Net income								414						414
Dividends								(150	)					(150	)
Other comprehensive loss, net of tax											(10	)		(10	)
Other								(1	)					(1	)
June 30, 2021		275	$	5,738	$	1,113	$	8,246		$	(33	)	$	15,064

YEAR-TO-DATE

	Common Stock
	Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total
(millions, except for shares)	(thousands)
December 31, 2019		275	$	5,738	$	1,113	$	7,167		$	(29	)	$	13,989
Net income								210						210
Dividends								(215	)					(215	)
Other comprehensive loss, net of tax											(41	)		(41	)
Other								1						1
June 30, 2020		275	$	5,738	$	1,113	$	7,163		$	(70	)	$	13,944

December 31, 2020		275	$	5,738	$	1,113	$	7,758		$	(52	)	$	14,557
Net income								788						788
Dividends								(300	)					(300	)
Other comprehensive income, net of tax											19			19
June 30, 2021		275	$	5,738	$	1,113	$	8,246		$	(33	)	$	15,064

Common Stock

Shares

Amount

Other Paid-In Capital

Retained Earnings

AOCI

Total

(millions, except for shares)

(thousands)

December 31, 2018

275

$
5,738

$
1,113

$
6,208

$
(12
)

$
13,047

Net income

120

120

Dividends

(189
)

(189
)
Other comprehensive loss, net of tax

(14
)

(14
)
June 30, 2019

275

$
5,738

$
1,113

$
6,139

$
(26
)

$
12,964

December 31, 2019

275

$
5,738

$
1,113

$
7,167

$
(29
)

$
13,989

Net income

210

210

Dividends

(215
)

(215
)
Other comprehensive loss, net of tax

(41
)

(41
)
Other

1

1

June 30, 2020

275

$
5,738

$
1,113

$
7,163

$
(70
)

$
13,944

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2020			2019			2021			2020
(millions)
Operating Activities
Net income	$	210		$	120		$	788		$	210
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		702			690			723			702
Deferred income taxes and investment tax credits		(220	)		(43	)		218			(220	)
Revision to future ash pond and landfill closure costs		—			(113	)
Impairment of assets and other charges		806			608
Charge related to a voluntary retirement program		—			190
Impairment of assets and other charges (benefit)								(39	)		806
Other adjustments		2			(51	)		81			24
Changes in:
Accounts receivable		1			68			88			(21	)
Affiliated receivables and payables		220			(179	)		(208	)		220
Inventories		(1	)		(30	)		25			(1	)
Prepayments		—			(4	)		(4	)		0
Deferred fuel expenses, net		136			153			(277	)		136
Accounts payable		(9	)		(35	)		15			(9	)
Accrued interest, payroll and taxes		18			14			43			18
Net realized and unrealized changes related to derivative activities		(20	)		17			51			(20	)
Other operating assets and liabilities		47			(331	)		(220	)		47
Net cash provided by operating activities		1,892			1,074			1,284			1,892
Investing Activities
Plant construction and other property additions		(1,474	)		(1,079	)		(1,575	)		(1,474	)
Purchases of nuclear fuel		(154	)		(67	)		(73	)		(154	)
Acquisition of solar development projects		(19	)		(150	)		(19	)		(19	)
Proceeds from sales of securities		530			447			1,249			530
Purchases of securities		(549	)		(478	)		(1,262	)		(549	)
Other		18			(11	)		(22	)		18
Net cash used in investing activities		(1,648	)		(1,338	)		(1,702	)		(1,648	)
Financing Activities
(Repayment) issuance of short-term debt, net		(243	)		986
Issuance (repayment) of short-term debt, net								769			(243	)
Issuance (repayment) of affiliated current borrowings, net		233			(153	)		(32	)		233
Issuance of long-term debt		105			198
Repayment of long-term debt		(105	)		(589	)
Issuance of long-term debt, net								0			105
Repayment of long-term debt, net								0			(105	)
Common dividend payments to parent		(215	)		(189	)		(300	)		(215	)
Other		(3	)		(2	)		(5	)		(3	)
Net cash provided by (used in) financing activities		(228	)		251			432			(228	)
Increase (decrease) in cash, restricted cash and equivalents		16			(13	)
Increase in cash, restricted cash and equivalents								14			16
Cash, restricted cash and equivalents at beginning of period		24			38			35			24
Cash, restricted cash and equivalents at end of period	$	40		$	25		$	49		$	40
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	239		$	193
Financing leases		20			9

See Note 2 for disclosure of supplemental cash flow information.

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

~~DOMINION ENERGY GAS HOLDINGS, LLC~~

~~CONSOLIDATED STATEMENTS OF INCOME~~

~~(Unaudited)~~

Three Months Ended June 30,

Six Months Ended June 30,

2020

2019

2020

2019

(millions)

Operating Revenue⁽¹⁾

$
510

$
530

$
1,066

$
1,096

Operating Expenses

Purchased (excess) gas⁽¹⁾

—

(3
)

8

9

Other energy-related purchases

1

1

1

1

Other operations and maintenance:

Affiliated suppliers

39

54

79

93

Other

111

156

236

293

Depreciation and amortization

94

92

187

182

Other taxes

35

38

77

78

Impairment of assets and other charges

482

13

482

13

Total operating expenses

762

351

1,070

669

Income (loss) from continuing operations

(252
)

179

(4
)

427

Earnings from equity method investees

8

9

23

22

Other income⁽¹⁾

46

44

95

85

Interest and related charges⁽¹⁾

50

86

108

173

Income (loss) from continuing operations before income tax expense

(248
)

146

6

361

Income tax expense (benefit)

(82
)

23

(30
)

66

Net income (loss) from continuing operations

(166
)

123

36

295

Net income from discontinued operations

—

26

—

80

Net income (loss) including noncontrolling interests

(166
)

149

36

375

Noncontrolling interests

32

30

65

66

Net Income (Loss) attributable to Dominion Energy Gas

$
(198
)

$
119

$
(29
)

$
309

~~(1)~~

~~See Note 19 for amounts attributable to related parties.~~

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

~~DOMINION ENERGY GAS HOLDINGS, LLC~~

~~CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME~~

~~(Unaudited)~~

Three Months Ended June 30,

Six Months Ended June 30,

2020

2019

2020

2019

(millions)

Net income (loss) including noncontrolling interests

$
(166
)

$
149

$
36

$
375

Other comprehensive income (loss), net of taxes:

Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾

—

(24
)

(91
)

(51
)
Changes in unrecognized pension and other postretirement benefits⁽²⁾

—

29

—

29

Amounts reclassified to net income (loss):

Net derivative (gains) losses-hedging activities⁽³⁾

(2
)

(2
)

4

1

Net pension and other postretirement benefit costs⁽⁴⁾

2

2

3

3

Total other comprehensive income (loss)

—

5

(84
)

(18
)
Comprehensive income (loss) including noncontrolling interests

(166
)

154

(48
)

357

Comprehensive income attributable to noncontrolling interests

32

30

65

65

Comprehensive income (loss) attributable to Dominion Energy Gas

$
(198
)

$
124

$
(113
)

$
292

~~(1)~~

Net of $(1) million and $8 million tax for the three months ended June 30, 2020 and 2019, respectively, and $31 million and $17 million tax for the six months ended June 30, 2020 and 2019, respectively.

~~(2)~~

~~Net of $~~ — ~~million and $(11) million tax for the three months ended June 30, 2020 and 2019, respectively, and $~~ — ~~million and $(11) million tax for the six months ended June 30, 2020 and 2019, respectively.~~

~~(3)~~

~~Net of $~~ — ~~million and $~~— ~~million tax for the three months ended June 30, 2020 and 2019, respectively, and $(2) million and $~~ — ~~million tax for the six months ended June 30, 2020 and 2019, respectively.~~

~~(4)~~

~~Net of $~~ — ~~million and $~~ — ~~million tax for the three months ended June 30, 2020 and 2019, respectively, and $(1) million and $(1) million tax for the six months ended June 30, 2020 and 2019, respectively.~~

~~The accompanying notes are an integral part of Dominion Energy Gas’ Consolidated Financial Statements.~~21

~~DOMINION ENERGY GAS HOLDINGS, LLC~~

~~CONSOLIDATED BALANCE SHEETS~~

~~(Unaudited)~~

June 30, 2020

December 31, 2019⁽¹⁾

(millions)

ASSETS

Current Assets

Cash and cash equivalents

$
53

$
27

Customer receivables (less allowance for doubtful accounts of $5 and $2)

151

173

Other receivables⁽²⁾

12

26

Affiliated receivables

77

362

Affiliated notes receivable

263

—

Inventories

130

122

Prepayments

43

73

Gas imbalances⁽²⁾

25

52

Other

23

23

Total current assets

777

858

Investments

Affiliated notes receivable

2,272

3,437

Investment in equity method affiliates

310

312

Total investments

2,582

3,749

Property, Plant and Equipment

Property, plant and equipment

14,899

15,166

Accumulated depreciation and amortization

(3,695
)

(3,538
)
Total property, plant and equipment, net

11,204

11,628

Deferred Charges and Other Assets

Goodwill

1,471

1,471

Other⁽²⁾

1,107

1,078

Total deferred charges and other assets

2,578

2,549

Total assets

$
17,141

$
18,784

~~(1)~~

~~Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2019 has been derived from the audited Consolidated Balance Sheet at that date.~~

~~(2)~~

~~See Note 19 for amounts attributable to related parties.~~

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

~~DOMINION ENERGY GAS HOLDINGS, LLC~~

~~CONSOLIDATED BALANCE SHEETS—(Continued)~~

~~(Unaudited)~~

June 30, 2020

December 31, 2019⁽¹⁾

(millions)

LIABILITIES AND EQUITY

Current Liabilities

Securities due within one year

$
1,200

$
700

Short-term debt

—

62

Accounts payable

52

59

Payables to affiliates

159

82

Affiliated current borrowings

314

260

Other⁽²⁾

382

289

Total current liabilities

2,107

1,452

Long-Term Debt

Long-term debt

4,324

4,821

Finance leases

5

5

Total long-term debt

4,329

4,826

Deferred Credits and Other Liabilities

Deferred income taxes and investment tax credits

1,156

1,288

Other

1,093

989

Total deferred credits and other liabilities

2,249

2,277

Total liabilities

8,685

8,555

Commitments and Contingencies (see Note 17)

Equity

Membership interests

7,352

9,031

Accumulated other comprehensive loss

(271
)

(187
)
Total members' equity

7,081

8,844

Noncontrolling interests

1,375

1,385

Total equity

8,456

10,229

Total liabilities and equity

$
17,141

$
18,784

~~(1)~~

~~Dominion Energy Gas’ Consolidated Balance Sheet at December 31, 2019 has been derived from the audited Consolidated Balance Sheet at that date.~~

~~(2)~~

~~See Note 19 for amounts attributable to related parties.~~

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

~~DOMINION ENERGY GAS HOLDINGS, LLC~~

~~CONSOLIDATED STATEMENTS OF EQUITY~~

~~(Unaudited)~~

~~QUARTER-TO-DATE~~

Predecessor Equity

Membership Interests

AOCI

Total Members' Equity

Noncontrolling Interests

Total

(millions)

March 31, 2019

$
2,938

$
4,682

$
(191
)

$
7,429

$
1,432

$
8,861

Net income

72

47

119

30

149

Dividends and distributions

(153
)

(153
)

(36
)

(189
)
Other comprehensive income, net of tax

5

5

5

Other

2

2

2

June 30, 2019

$
2,859

$
4,729

$
(186
)

$
7,402

$
1,426

$
8,828

March 31, 2020

$
—

$
8,968

$
(271
)

$
8,697

$
1,381

$
10,078

Net income (loss)

(198
)

(198
)

32

(166
)
Dividends and distributions

(1,418
)

(1,418
)

(38
)

(1,456
)
June 30, 2020

$
—

$
7,352

$
(271
)

$
7,081

$
1,375

$
8,456

~~YEAR-TO-DATE~~

Predecessor Equity

Membership Interests

AOCI

Total
Members'
Equity

Noncontrolling Interests

Total

(millions)

December 31, 2018

$
1,804

$
4,566

$
(169
)

$
6,201

$
2,664

$
8,865

Net income

146

163

309

66

375

Acquisition of public interest in Dominion Energy Midstream

1,181

1,181

(1,221
)

(40
)
Dividends and distributions

(266
)

(266
)

(82
)

(348
)
Other comprehensive loss, net of tax

(17
)

(17
)

(1
)

(18
)
Other

(6
)

(6
)

(6
)
June 30, 2019

$
2,859

$
4,729

$
(186
)

$
7,402

$
1,426

$
8,828

December 31, 2019

$
—

$
9,031

$
(187
)

$
8,844

$
1,385

$
10,229

Net income (loss)

(29
)

(29
)

65

36

Dividends and distributions

(1,650
)

(1,650
)

(75
)

(1,725
)
Other comprehensive loss, net of tax

(84
)

(84
)

(84
)
June 30, 2020

$
—

$
7,352

$
(271
)

$
7,081

$
1,375

$
8,456

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

~~DOMINION ENERGY GAS HOLDINGS, LLC~~

~~CONSOLIDATED STATEMENTS OF CASH FLOWS~~

~~(Unaudited)~~

Six Months Ended June 30,

2020

2019

(millions)

Operating Activities

Net income including noncontrolling interests

$
36

$
375

Adjustments to reconcile net income to net cash provided by operating activities:

Depreciation and amortization

187

227

Deferred income taxes and investment tax credits

(97
)

39

Charge related to a voluntary retirement program

—

73

Impairment of assets and other charges

482

13

Other adjustments

(1
)

15

Changes in:

Accounts receivable

37

88

Affiliated receivables and payables

362

(48
)
Inventories

(8
)

(31
)
Prepayments

30

59

Accounts payable

6

(105
)
Accrued interest, payroll and taxes

(16
)

(55
)
Customer deposits

(1
)

(81
)
Pension and other postretirement benefits

(35
)

(64
)
Other operating assets and liabilities

26

(45
)
Net cash provided by operating activities

1,008

460

Investing Activities

Plant construction and other property additions

(147
)

(341
)
Repayment of loans by affiliates

1,165

—

Advances to affiliates

(263
)

—

Other

(4
)

(12
)
Net cash provided by (used in) investing activities

751

(353
)
Financing Activities

Issuance (repayment) of short-term debt, net

(62
)

240

Issuance (repayment) of affiliated current borrowings, net

54

(11
)
Repayment of long-term debt

—

(300
)
Issuance of affiliated long-term debt

—

395

Repayment of credit facility borrowings

—

(73
)
Dividends and distributions

(1,725
)

(348
)
Other

(1
)

(1
)
Net cash used in financing activities

(1,734
)

(98
)
Increase in cash, restricted cash and equivalents

25

9

Cash, restricted cash and equivalents at beginning of period

39

198

Cash, restricted cash and equivalents at end of period

$
64

$
207

Supplemental Cash Flow Information

Significant noncash investing activities:

Accrued capital expenditures

$
24

$
43

Financing leases

1

6

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

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1. Nature of Operations

Dominion Energy, headquartered in Richmond, Virginia, is one of the nation’s largest producers and ~~transporters~~distributors of energy. Dominion Energy’s operations are conducted through various subsidiaries, including Virginia ~~Power and Dominion Energy Gas.~~Power. Dominion Energy’s operations also include DESC, ~~an equity investment in Atlantic Coast Pipeline and~~ regulated gas distribution operations primarily in the eastern and Rocky Mountain regions of the U.S. ~~Dominion Energy’s~~, nonregulated ~~operations include merchant~~electric generation and, retail energy marketing operations. Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina. Dominion Energy Gas is a holding company that conducts business activities through FERC-regulated interstate natural gas transmission pipeline and underground storage systems in the eastern and Rocky Mountain regionsfollowing completion of the ~~U.S., as well as the Cove Point LNG Facility. In addition, Dominion Energy Gas owns~~GT&S Transaction in November 2020, a ~~50%~~ noncontrolling interest in ~~both Iroquois and White River Hub.~~Cove Point. See Note 3 for ~~additional information on~~a description of the ~~Dominion Energy Gas Restructuring. In July 2020, Dominion Energy entered an agreement to sell~~sale of substantially all of ~~its~~Dominion Energy’s gas transmission and storage operations ~~including~~to BHE through the GT&S Transaction completed in November 2020 and the anticipated sale of Dominion ~~Energy Gas, to BHE. See Note 3 for additional information.~~Energy’s remaining regulated gas transmission and storage services in the Rocky Mountain region of the U.S.

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, ~~2019.~~2020.

In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position at June 30, ~~2020,~~2021, their results of operations and changes in equity for the three and six months ended June 30, ~~2020~~2021 and ~~2019~~2020 and their cash flows for the six months ended June 30, ~~2020~~2021 and ~~2019.~~2020. 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 and expenses 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. At June 30, ~~2020,~~2021, Dominion Energy owns 50% of the voting interests in Four Brothers and Three Cedars and has a controlling financial interest over the entities through its right to control operations. GIP’s ownership interest in Four Brothers and Three Cedars, Terra Nova Renewable Partners’ 33% interest in certain Dominion Energy ~~merchant~~nonregulated solar projects and Brookfield’s 25% interest in Cove Point (effective December ~~2019) and the non-Dominion Energy held interest in Dominion Energy Midstream (through January 2019)~~2019 until November 2020) are reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. In August 2021, Dominion Energy entered into an agreement with Terra Nova Renewable Partners ~~has a future option~~ to ~~buy all or a portion of Dominion Energy’s~~sell its remaining ~~67% ownership~~controlling financial interest in certain merchant projects upon the occurrence of certain events, none of which are expected to occur in the next 12 months. Brookfield’s 25% interest in Cove Point (effective December 2019) and the public’s ownership interest in Dominion Energy Midstream (through January 2019) are reflected as noncontrolling interest in Dominion Energy Gas’ Consolidated Financial Statements.nonregulated solar projects. See Note 11 for more information.

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’ ~~2019~~2020 Consolidated Financial Statements and Notes have been reclassified to conform to the ~~2020~~2021 presentation for comparative purposes; however, such reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows. Effective in the second quarter of 2021, the Companies updated their Statements of Cash Flows to present net charges for allowance for credit risk and write-offs of accounts receivables within other adjustments to reconcile net income to net cash provided by operating activities from the previous presentation within changes in accounts receivable. All prior period information has been conformed to this presentation, which does not result in a change to net cash provided by operating activities.

Amounts disclosed for Dominion Energy are inclusive of Virginia Power, ~~and/or Dominion Energy Gas,~~ 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, ~~2019,~~2020, 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 six months ended June 30, ~~2020~~2021 and ~~2019:~~2020:

Cash, Restricted Cash and Equivalents
at End of Period

Cash, Restricted Cash and Equivalents
at Beginning of Period

June 30, 2020

June 30, 2019

December 31, 2019

December 31, 2018

(millions)

Dominion Energy

Cash and cash equivalents

$
675

$
382

$
166

$
268

Restricted cash and equivalents⁽¹⁾

67

178

103

123

Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows

$
742

$
560

$
269

$
391

Virginia Power

Cash and cash equivalents

$
37

$
17

$
17

$
29

Restricted cash and equivalents⁽¹⁾

3

8

7

9

Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows

$
40

$
25

$
24

$
38

Dominion Energy Gas

Cash and cash equivalents⁽²⁾

$
53

$
195

$
27

$
108

Restricted cash and equivalents ⁽¹⁾

11

12

12

90

Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows

$
64

$
207

$
39

$
198

	Cash, Restricted Cash and Equivalents at End of Period				Cash, Restricted Cash and Equivalents at Beginning of Period
	June 30, 2021		June 30, 2020		December 31, 2020		December 31, 2019
(millions)
Dominion Energy
Cash and cash equivalents⁽¹⁾	$	259	$	675	$	179	$	166
Restricted cash and equivalents⁽²⁾⁽³⁾		45		67		68		103
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	304	$	742	$	247	$	269
Virginia Power
Cash and cash equivalents	$	49	$	37	$	35	$	17
Restricted cash and equivalents⁽³⁾		0		3		0		7
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	49	$	40	$	35	$	24

(1)	At June 30, 2021, June 30, 2020, December 31, 2020 and December 31, 2019, Dominion Energy had $19 million, $59 million, $7 million and $31 million of cash and cash equivalents included in current assets held for sale, respectively.

(2)	At June 30, 2021, June 30, 2020, December 31, 2020 and December 31, 2019, Dominion Energy had $3 million, $12 million, $3 million and $12 million of restricted cash and equivalents included in current assets held for sale, respectively.

(3)	Restricted cash and equivalent 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:

	Six Months Ended June 30,
	2021		2020
(millions)
Significant noncash investing and financing activities:
Accrued capital expenditures	$	327	$	346
Accrued contributions to equity method affiliates		20		5
Leases⁽¹⁾		29		35

~~(2)~~(1)

AtIncludes $22 million and $32 million of financing leases at June 30, ~~2019~~2021 and ~~December 31, 2018, Dominion Energy Gas had $12~~2020, respectively, and $7 million and $9$3 million of ~~cash~~operating leases at June 30, 2021 and ~~cash equivalents included in current assets of discontinued operations,~~2020, respectively.

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

	Six Months Ended June 30,
	2021		2020
(millions)
Significant noncash investing and financing activities:
Accrued capital expenditures	$	207	$	239
Financing leases		17		20

Property, Plant and Equipment

In January 2019, Virginia Power committed to a plan to retire certain automated metering reading infrastructure associated with its electric operations before the end of its estimated useful life and replace such equipment with more current AMI technology. As a result, Virginia Power recorded a charge of $160 million ($119 million after-tax) in the first quarter of 2019, included in impairment of assets and other charges in its Consolidated Statements of Income. This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13 to the Consolidated Financial Statements in Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2019.

In March 2019, Virginia Power committed to retire certain electric generating units before the end of their useful lives and completed the retirement of certain units at 6 facilities representing 1,292 MW of electric generating capacity, which had previously been placed in cold reserve. An additional unit at Possum Point power station will be retired after it meets its capacity obligation to PJM in 2021. As a result, Virginia Power recorded a charge of $369 million ($275 million after-tax) in the first quarter of 2019, primarily included in impairment of assets and other charges in its Consolidated Statements of Income. This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as discussed in Note 13 to the Consolidated Financial Statements in Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2019.

In May 2019, Virginia Power abandoned a coal rail project at its Mt. Storm generating facility. As a result, Virginia Power recorded a charge of $62 million ($46 million after-tax) in the second quarter of 2019, included in impairment of assets and other charges in its Consolidated Statements of Income.

In March 2020, Virginia Power committed to retire certain coal- and oil-fired generating units before the end of their useful lives based on economic and other factors, including but not limited to market power prices and the VCEA. These units will be retired after they meet their capacity obligations to PJM in 2023. As a result, Virginia Power recorded a charge of $754 million ($561 million after-tax) in the first quarter of 2020, primarily included in impairment of assets and other charges in its Consolidated Statements of Income. This charge is considered a component of Virginia Power’s base rates deemed recovered under the GTSA, subject to review as

discussed in Note 13 to the Consolidated Financial Statements in Virginia Power’s Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020.

In the second quarter of 2020, Virginia Power recorded charges of $30 million ($22 million after-tax) associated with dismantling certain of these electric generation facilities, recorded in impairment of assets and other charges in its Consolidated Statements of Income.

In the first quarter of 2020, Virginia Power updated depreciation rates for its nuclear plants to reflect lower depreciation rates as a result of the expected approval of license extensions from the NRC. This adjustment resulted in a decrease in depreciation expense of $8 million ($6 million after-tax) and $16 million ($12 million after-tax) for the three and six months ended June 30, 2020, respectively, in Virginia Power’s Consolidated Statements of Income and a $0.01 increase in Dominion Energy’s EPS, for both the three and six months ended June 30, 2020. This revision is expected to decrease annual depreciation expense by approximately $31 million ($23 million after-tax) and increase Dominion Energy’s EPS by $0.03 for the year ended December 31, 2020.Asset Retirement Obligations

In the second quarter of ~~2020, DESC completed a~~2021, Dominion Energy revised its estimated cash flow projections associated with the recovery of spent nuclear fuel costs for its AROs associated with the decommissioning ~~cost study related to Summer.~~of Kewaunee. As a result, ~~of the study,~~ Dominion Energy ~~recorded an $89 million increase to its nuclear decommissioning ARO, with a corresponding increase to property, plant and equipment.~~

In December 2014, DETI entered into a precedent agreement with Atlantic Coast Pipeline for the Supply Header Project. As a result of the cancellation of the Atlantic Coast Pipeline Project, Dominion Energy and Dominion Energy Gas recorded a charge of ~~$482~~$44 million ($~~359~~35 million after-tax) within other operations and maintenance expense in impairment of assets and other charges in their Consolidated Statements of Income for the three and six months ended June 30, 2020 associated with the probable abandonment of a significant portion of the project as well as the establishment of a $75 million ARO. As DETI evaluates its ~~future use, approximately $40 million remains within property, plant and equipment for a potential modified project.~~

~~Credit Risk~~

Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition, collateral requirements and the use of standardized agreements that facilitate the netting of cash flows associated with a single counterparty. In addition, counterparties may make available collateral, including letters of credit or cash held as margin deposits, as a result of exceeding agreed-upon credit limits, or may be required to prepay the transaction.

Effective January 2020, expected credit losses are estimated and recorded based on historical experience, current conditions and reasonable and supportable forecasts that affect the collectability of financial assets held at amortized cost as well as expected credit losses on commitments with respect to financial guarantees.

~~Investments~~

~~Debt and Equity Securities with Readily Determinable Fair Value~~

Dominion Energy accounts for and classifies investments in debt securities as trading or available-for-sale securities. Virginia Power classifies investments in debt securities as available-for-sale securities.

• ~~Debt securities classified as trading securities~~ include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income.

• ~~Debt securities classified as available-for-sale securities~~ include all other debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any credit-related impairments) on investments held in Virginia Power’s nuclear decommissioning trusts are deferred to a regulatory asset or liability as applicable for certain jurisdictions subject to cost-based regulation. For all other available-for-sale debt securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts, net realized gains and losses (including any credit-related impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax.

~~In determining realized gains and losses for debt securities, the cost basis of the security is based on the specific identification method.~~

Equity securities with readily determinable fair values include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans and securities held by Dominion Energy and Virginia Power in the nuclear decommissioning

trusts. Dominion Energy and Virginia Power record all equity securities with a readily determinable fair value, or for which they are permitted to estimate fair value using NAV (or its equivalent), at fair value in nuclear decommissioning trust funds and other investments in the Consolidated Balance Sheets. However, Dominion Energy and Virginia Power may elect a measurement alternative for equity securities without a readily determinable fair value. Under the measurement alternative, equity securities are reported at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer. Dominion Energy and Virginia Power qualitatively assess equity securities reported using the measurement alternative to determine whether an investment is impaired on an ongoing basis. Net realized and unrealized gains and losses on equity securities held in Virginia Power’s nuclear decommissioning trusts are deferred to a regulatory asset or liability, as applicable, for certain jurisdictions subject to cost-based regulation. For all other equity securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts and rabbi trusts, net realized and unrealized gains and losses are included in other income in the Consolidated Statements of Income.

~~Equity Securities without Readily Determinable Fair Values~~

The Companies account for illiquid and privately held securities without readily determinable fair values under either the equity method or cost method. Equity securities without readily determinable fair values include:

• ~~Equity method investments~~ when the Companies have the ability to exercise significant influence, but not control, over the investee. Dominion Energy and Dominion Energy Gas’ investments are included in investments in equity method affiliates in their Consolidated Balance Sheets. Dominion Energy and Dominion Energy Gas record equity method adjustments in other income and earnings from equity method investees, respectively, in their Consolidated Statements of Income, including their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method.

• ~~Cost method investments~~ when Dominion Energy and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion Energy and Virginia Power’s investments are included in other investments and nuclear decommissioning trust funds. Cost method investments are reported at cost less impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for identical or similar investments of the same issuer.

~~Other-Than-Temporary Impairment~~

The Companies periodically review their equity method investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in the fair value of any equity method investment is determined to be other-than-temporary, the investment is written down to its fair value at the end of the reporting period.

~~Credit Impairment~~

Effective January 2020, Dominion Energy and Virginia Power periodically review their available-for-sale debt securities to determine whether a decline in fair value should be considered credit related. If a decline in the fair value of any available-for-sale debt security is determined to be credit related, the credit-related impairment is recorded to an allowance included in nuclear decommissioning trust funds in Dominion Energy and Virginia Power’s Consolidated Balance Sheets at the end of the reporting period, with such allowance for credit losses subject to reversal in subsequent evaluations.

Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion Energy and Virginia Power record in earnings, or defer as applicable for certain jurisdictions subject to cost-based regulation, any unrealized loss for a debt security when the manager intends to sell the debt security or it is more-likely-than-not that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, Dominion Energy and Virginia Power record the credit loss in earnings with the remaining non-credit portion of the unrealized loss recorded in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors.

Note 3. Acquisitions and Dispositions

~~Acquisition of SCANA~~

In January 2019, Dominion Energy issued 95.6 million shares of Dominion Energy common stock, valued at $6.8 billion, representing 0.6690 of a share of Dominion Energy common stock for each share of SCANA common stock, in connection with the completion of the SCANA Combination. SCANA, through its regulated subsidiaries, is primarily engaged in the generation, transmission and distribution of electricity in the central, southern and southwestern portions of South Carolina and in the distribution of natural gas in

North Carolina and South Carolina. In addition, at the closing of the SCANA Combination, SCANA marketed natural gas to retail customers in the southeast U.S. Following completion of the SCANA Combination, SCANA operates as a wholly-owned subsidiary of Dominion Energy. In addition, SCANA’s debt totaled $6.9 billion at closing. The SCANA Combination expanded Dominion Energy’s portfolio of regulated electric generation, transmission and distribution and regulated natural gas distribution infrastructure operations.

See Note 3 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019 for more information on the SCANA Combination, including merger approval and conditions, information on assets acquired and liabilities assumed and purchase price allocation. In addition, see Note 17 for a discussion of certain legal proceedings involving Dominion Energy, SCANA or DESC relating to events occurring before closing of the SCANA Combination.

~~In accordance with the SCANA Merger Approval Order, Dominion Energy incurred certain charges to its Consolidated Statements of Income for the following:~~

•

In the first quarter of 2019, DESC recorded a reduction in operating revenue and a corresponding regulatory liability of $1.0 billion representing a refund of amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period, effective January 2019, As a result, Dominion Energy’s Consolidated Statement of Income for the six months ended June 30, 2019 includes a $756 million after-tax charge.

•

Dominion Energy committed to forgo recovery of $105 million of certain property, plant and equipment associated with the NND Project. As a result, Dominion Energy’s Consolidated Statement of Income for the six months ended June 30, 2019 includes a charge of $105 million ($79 million after-tax), included in impairment of assets and other charges.

•

Dominion Energy committed to forgo recovery of $264 million of certain income tax-related regulatory assets associated with the NND Project. As a result, Dominion Energy’s Consolidated Statement of Income for the six months ended June 30, 2019 includes a charge of $198 million included in income tax expense.

~~Results of Operations and Unaudited Pro Forma Information~~

The impact of the SCANA Combination on Dominion Energy’s operating revenue was an increase of $701 million and $909 million for the three months ended June 30, 2020 and 2019, respectively, and an increase of $1.6 billion and $1.1 billion for the six months ended June 30, 2020 and 2019, respectively, in the Consolidated Statements of Income. The impact of the SCANA Combination on net income attributable to Dominion Energy was an increase of $58 million and a decrease of $102 million for the three months ended June 30, 2020 and 2019, respectively, and an increase of $112 million and a decrease of $1.2 billion for the six months ended June 30, 2020 and 2019, respectively, in the Consolidated Statements of Income.

Dominion Energy incurred merger and integration-related costs of $23 million and $42 million for the three and six months ended June 30, 2020, respectively, of which $20 million and $39 million are recorded in other operations and maintenance expense in the Consolidated Statements of Income. Dominion Energy incurred merger and integration-related costs of $443 million and $567 million in the Consolidated Statements of Income for the three and six months ended June 30, 2019, respectively. These amounts for both the three and six months ended June 30, 2019 include $423 million for a charge related to a voluntary retirement program. See Note 20 for additional information. Of the remaining merger and integration-related costs, $20 million and $135 million was recorded in other operations and maintenance expense in the Consolidated Statements of Income for the three and six months ended June 30, 2019, respectively, and $9 million was recorded in interest and related charges in the Consolidated Statement of Income for the six months ended June 30, 2019. There were 0 such charges recorded in interest and related charges for the three months ended June 30, 2019. These costs consist of professional fees, charitable contribution commitments, employee-related expenses, certain financing costs and other miscellaneous costs.

The following unaudited pro forma financial information reflects the consolidated results of operations of Dominion Energy assuming the SCANA Combination had taken place on January 1, 2018. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of the combined company.

Three Months Ended
June 30, 2019⁽¹⁾

Six Months Ended
June 30, 2019⁽¹⁾

(millions, except EPS)

Operating Revenue

$
3,970

$
8,835

Net income attributable to Dominion Energy

392

962

Earnings Per Common Share – Basic

$
0.49

$
1.21

Earnings Per Common Share – Diluted

$
0.47

$
1.19

~~(1)~~

~~Amounts include adjustments for non-recurring costs directly related to the SCANA Combination.~~

Disposition of Gas Transmission & Storage Operations ~~to BHE~~

In July 2020, Dominion Energy entered into an agreement with BHE with a total value of approximately $10 billion, comprised of approximately $4.0 billion of cash consideration (subject to customary closing adjustments) plus the assumption of ~~Dominion Energy Gas’~~ long-term debt, to sell substantially all of its gas transmission and storage operations, including processing assets, as well as noncontrolling partnership interests in Iroquois, JAX LNG and White River Hub and a controlling interest in Cove Point (consisting of 100% of the general partner interest and 25% of the total limited partner interests). ~~Upon closing,~~The agreement provides that Dominion Energy Gas will become a wholly-owned subsidiary of BHE. Dominion Energy will retain a 50% noncontrolling interest in Cove Point, which will be accounted for as an equity method investment following completion of the sale, as well asretains the assets and obligations of the pension and other postretirement employee benefit plans associated with the operations ~~to be sold~~included in the transaction and relating to services provided through closing. In October 2020, pursuant to a provision in the agreement with BHE, Dominion Energy elected to exclude the Q-Pipe Group from the transaction as approval under the Hart-Scott-Rodino Act had not been obtained by mid-September 2020. Concurrently in October 2020, Dominion Energy and BHE entered into a separate agreement under which Dominion Energy would sell the Q-Pipe Group for cash consideration of $1.3 billion and the assumption of related long-term debt. In November 2020, Dominion Energy completed the GT&S Transaction as discussed in Note 3 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2020.

In connection with closing of the GT&S Transaction, Dominion Energy and BHE entered into a transition services agreement under which Dominion Energy will continue to provide specified administrative services to support the operations of the disposed business for up to 24 months after closing. In addition, BHE will provide certain administrative services to Dominion Energy. Dominion Energy recorded revenue of $6 million and $11 million associated with the transition service agreement in operating revenue in its Consolidated Statements of Income for the three and six months ended June 30, 2021, respectively.

Also in November 2020, BHE provided a $1.3 billion deposit to Dominion Energy on the Q-Pipe Transaction. In July 2021, Dominion Energy and BHE mutually agreed to terminate the Q-Pipe Transaction as a result of ongoing uncertainty associated with receiving approval under the Hart-Scott-Rodino Act. Dominion Energy simultaneously announced its intention to pursue the divestiture of the Q-Pipe Group to an alternative buyer via competitive sales process with targeted closing, subject to applicable regulatory approval, by the end of 2021. Also in July 2021, Dominion Energy entered into an approximately $1.3 billion term loan credit agreement and borrowed the full amount available thereunder. The agreement matures in December 2021, which can be extended at Dominion Energy’s option to June 2022, and bears interest at a variable rate. The proceeds were utilized to repay the deposit received from BHE on the Q-Pipe Transaction. Upon completion of a sale of the Q-Pipe Group, Dominion Energy is required to utilize the net proceeds to repay any outstanding balances under the term loan agreement. The operations of the Q-Pipe Group continue to meet the classification as held-for-sale based on Dominion Energy’s plan to complete a sale of the entities.

The operations included in both the GT&S Transaction and the Q-Pipe Group are presented in held-for-sale and discontinued operations effective July 2020. As a result, the previously reported amounts have been recast to reflect this presentation and depreciation and amortization ceased on the applicable assets. As Cove Point had previously been consolidated within Dominion Energy’s financial statements, balances associated with Cove Point prior to the closing of the GT&S Transaction are presented within held-for-sale and discontinued operations. See Note 10 for further information regarding Dominion Energy’s equity method investment in Cove Point.

The following table represents selected information regarding the results of operations, which are reported within discontinued operations in Dominion Energy’s Consolidated Statements of Income:

	Three Months Ended June 30, 2021		Three Months Ended June 30, 2020					Six Months Ended June 30, 2021		Six Months Ended June 30, 2020
	Q-Pipe Group		GT&S Transaction			Q-Pipe Group		Q-Pipe Group		GT&S Transaction			Q-Pipe Group
(millions)
Operating revenue	$	59	$	480		$	58	$	126	$	1,043		$	123
Operating expense⁽¹⁾		9		770			29		28		1,103			62
Other income		1		12			1		1		32			2
Interest and related charges		5		46			6		10		99			10
Income (loss) before income taxes		46		(324	)		24		89		(127	)		53
Income tax expense (benefit)		9		(78	)		10		17		(51	)		14
Net income (loss) including noncontrolling interests		37		(246	)		14		72		(76	)		39
Noncontrolling interests		—		32			—		—		65			—
Net income (loss) attributable to Dominion Energy	$	37	$	(278	)	$	14	$	72	$	(141	)	$	39

(1)

GT&S Transaction includes a charge of $482 million ($359 million after-tax) recorded in the second quarter of 2020 associated with the probable abandonment of a significant portion of the Supply Header Project, as well as the establishment of a $75 million ARO as a result of the cancellation of the Atlantic Coast Pipeline Project.

The carrying amounts of major classes of assets and liabilities relating to the disposal groups, which are reported as held for sale in Dominion Energy’s Consolidated Balance Sheets were as follows:

	At June 30, 2021		At December 31, 2020
	Q-Pipe Group		Q-Pipe Group
(millions)
Current assets⁽¹⁾	$	51	$	47
Equity method investments⁽²⁾		35		35
Property, plant and equipment, net		1,138		1,113
Other deferred charges and other assets, including goodwill and intangible assets⁽³⁾		223		224
Current liabilities		34		30
Long-term debt		426		426
Other deferred credits and liabilities		154		154

(1)

Includes cash and cash equivalents of $18 million and $7 million as of June 30, 2021 and December 31, 2020, respectively.

(2)

Comprised of an equity method investment in White River Hub.

(3)

Includes goodwill of $191 million at both June 30, 2021 and December 31, 2020.

Capital expenditures and significant noncash items relating to the disposal groups included the following:

	Six Months Ended June 30, 2021		Six Months Ended June 30, 2020
	Q-Pipe Group		GT&S Transaction		Q-Pipe Group
(millions)
Capital expenditures	$	15	$	138	$	15
Significant noncash items:
Impairment of assets and other charges		0		482		1
Depreciation, depletion and amortization		0		164		26
Accrued capital expenditures		4		28		1

Sale of Kewaunee

In May 2021, Dominion Energy entered into an agreement to sell 100% of the equity interests in Dominion Energy Kewaunee, Inc. to EnergySolutions, including the transfer of all decommissioning obligations associated with Kewaunee, which ceased operations in

2013. The agreement provides that Dominion Energy retains the assets and obligations of the pension and other postretirement employee benefit plans. In addition, Dominion Energy may continue to withdraw funds prior to closing from the nuclear decommissioning trust to recover certain spent nuclear fuel and other permitted costs, subject to certain conditions. The sale will be treated as an asset sale for tax purposes and is ~~expected~~subject to ~~close in the fourth quarter of 2020,~~termination by either party if not completed by December 2022. Closing is contingent on ~~clearance or~~ approval ~~under the Hart-Scott-Rodino Act and~~ from the ~~DOE,~~Wisconsin Commission as well as the NRC for the transfer of control of applicable licenses. The purchase agreement requires that EnergySolutions be subject to the Wisconsin regulatory conditions agreed to by Dominion Energy upon its acquisition of Kewaunee, including the return of any excess decommissioning funds to WPSC and ~~other customary closing~~WP&L customers following completion of all decommissioning activities.

In May 2021, Dominion Energy and ~~regulatory conditions. Based on~~EnergySolutions submitted a license transfer application to the ~~recorded balances at~~NRC. Also in May 2021, Dominion Energy submitted an application to the Wisconsin Commission for approval. In July 2021, WPSC and WP&L submitted a joint request to the Wisconsin Commission for the waiver of both of their rights of first refusal to purchase Kewaunee, such rights having been granted as the former owners of Kewaunee. At June 30, ~~2020,~~ 2021, Dominion Energy determined that the assets and liabilities associated with the Kewaunee sale did not meet the criteria to be classified as held for sale due to the significant uncertainty surrounding the timing of or ability to obtain necessary regulatory approvals.

Dominion Energy expects to ~~recognize~~record a ~~pre-tax gain of approximately $1 billion upon closing, excluding~~loss if and when it determines that criteria for the effects of any closing adjustments. If approval under the Hart-Scott-Rodino Act is not obtained by mid-September 2020, Dominion Energy may elect to exclude from this transaction Dominion Energy Questar Pipeline and certain other affiliated entities pursuant to a provision in the agreement with BHE, with an associated reduction in the cash consideration to $2.7 billion, subject to customary closing adjustments.

~~Dominion Energy will reclassify the assets and liabilities to be disposed of, currently reflected within Gas Transmission & Storage,~~classification as held for sale have been met. If such classification had been made at June 30, 2021, Dominion Energy would have recognized a loss of approximately $725 million ($570 million after-tax). If the sale is ultimately completed, the final net loss will primarily depend on the value of the nuclear decommissioning trust and ~~will report~~AROs at closing.

Acquisition of Birdseye

In May 2021, Dominion Energy acquired 100% of the ~~associated results~~ownership interest in Birdseye from BRE Holdings, LLC for total consideration of ~~operations as discontinued operations starting~~$46 million, consisting of $28 million in cash and $18 million, measured at fair value at closing, of consideration contingent on the achievement of certain revenue targets and future development project sales. Birdseye is primarily engaged in the ~~third quarter~~development of ~~2020. In addition,~~solar energy projects in southeastern states in the ~~third quarter~~U.S. with 2.5 GW of ~~2020, Dominion Energy~~solar generation projects under development. The allocation of the purchase price resulted in $25 million of development project assets, primarily reflected in other deferred charges and ~~Dominion Energy Gas expect to record pre-tax losses of approximately $225 million and $140 million, respectively, for cash flow hedges of debt-related items that are probable of not occurring.~~

~~Dominion Energy Gas Restructuring~~

~~The Dominion Energy Gas Restructuring is considered to be a reorganization of entities under common control. As a result, Dominion Energy Gas’ basis~~other assets in DCP and DMLPHCII, which includes the general partner of Dominion Energy Midstream, a controlling 75% interest in Cove Point, DECG, Dominion Energy Questar Pipeline, a 50% noncontrolling interest in White River Hub and a 25.93% noncontrolling interest in Iroquois, is equal to Dominion Energy’s ~~cost basis in~~Consolidated Balance Sheets, and $24 million of goodwill, which is not deductible for tax purposes. The goodwill reflects the value associated with enhancing Dominion Energy's development of regulated and long-term contracted solar generating and electric storage projects. The fair value measurements, including of the assets acquired, were determined using the income approach and ~~liabilities~~are considered Level 3 fair value measurements due to the use of ~~such entities since the applicable inception dates~~significant judgmental and unobservable inputs, including projected timing and amount of common control. In November 2019, following completion of the Dominion Energy Gas Restructuring, DCP and DMLPHCII are wholly-owned subsidiaries of Dominion Energy Gas and therefore are consolidated by Dominion Energy Gas. The accompanying Consolidated Financial Statements and Notes of Dominion Energy Gas have been retrospectively adjusted to include the historical results and financial position of DCP and DMLPHCII. The 25% interestfuture cash flows. Birdseye is included in Cove Point retained by Dominion Energy, and subsequently sold to Brookfield in December 2019, and the non-Dominion Energy held interest in Dominion Energy Midstream (through January 2019) are reflected as noncontrolling interest.

The Dominion Energy Gas Restructuring includes the disposition of East Ohio and DGP by Dominion Energy Gas in November 2019. This restructuring represented a strategic shift in the operations of Dominion Energy Gas as Dominion Energy Gas’ operations consist of LNG import/export and storage and regulated gas transmission and storage operations. As a result, the accompanying Consolidated Financial Statements and Notes of Dominion Energy Gas have been retrospectively adjusted to include the historical results and financial position of East Ohio and DGP as discontinued operations until November 2019, presented within the Corporate and Other segment. As the Dominion Energy Gas Restructuring is considered to be a reorganization of entities under common control, Dominion Energy Gas has reflected the disposition as an equity transaction. The following table represents selected information regarding the results of operations of East Ohio, which are reported as discontinued operations in Dominion Energy Gas’ Consolidated Statements of Income:

Three Months Ended
June 30, 2019

Six Months Ended
June 30, 2019

(millions)

Operating revenue

$
154

$
383

Depreciation and amortization

22

43

Other operating expenses

128

277

Other income

18

37

Interest and related charges

8

18

Income tax expense

3

17

Net income from discontinued operations

$
11

$
65

~~Capital expenditures and significant noncash items relating to East Ohio included the following:~~

Six Months Ended
June 30, 2019

(millions)

Capital expenditures

$
168

Significant noncash items

Charge related to a voluntary retirement program

32

Accrued capital expenditures

8

The following table represents selected information regarding the results of operations of DGP, which are reported as discontinued operations in Dominion Energy Gas’ Consolidated Statements of Income:

Three Months Ended
June 30, 2019

Six Months Ended
June 30, 2019

(millions)

Operating revenue

$
34

$
79

Depreciation and amortization

1

2

Other operating expenses

12

56

Income tax expense

6

6

Net income from discontinued operations

$
15

$
15

~~Capital expenditures and significant noncash items of DGP included the following:~~

Six Months Ended
June 30, 2019

(millions)

Capital Expenditures

$
8

Contracted Assets.

Note 4. Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,					Six Months Ended June 30,
	2020		2019		2020		2019		2021			2020		2021			2020
(millions)
Dominion Energy
Regulated electric sales:
Residential	$	1,091	$	1,094	$	2,249	$	1,740	$	1,017		$	1,091	$	2,172		$	2,249
Commercial		728		889		1,526		1,385		761			728		1,480			1,526
Industrial		176		217		358		247		175			176		353			358
Government and other retail		193		214		412		414		223			193		412			412
Wholesale		29		41		62		89		36			29		79			62
Nonregulated electric sales		177		175		409		491		217			177		466			409
Regulated gas sales:
Residential		182		177		730		779		188			182		818			730
Commercial		63		73		254		264		79			63		285			254
Other		16		25		44		63		23			17		57			45
Nonregulated gas sales		33		71		116		318		15			29		67			112
Regulated gas transportation and storage:
FERC-regulated		247		247		528		524
State-regulated		182		166		414		379
Nonregulated gas transportation and storage		176		174		351		348
Other regulated revenues⁽¹⁾		98		82		173		126
Other nonregulated revenues⁽¹⁾⁽²⁾		79		101		167		209
Regulated gas transportation and storage										219			182		490			414
Other regulated revenues										74			96		140			151
Other nonregulated revenues⁽¹⁾										57			39		105			70
Total operating revenue from contracts with customers		3,470		3,746		7,793		7,376		3,084			3,002		6,924			6,792
Other revenues⁽³⁾		115		224		288		452
Other revenues⁽²⁾⁽³⁾										(46	)		104		(16	)		252
Total operating revenue	$	3,585	$	3,970	$	8,081	$	7,828	$	3,038		$	3,106	$	6,908		$	7,044
Virginia Power
Regulated electric sales:
Residential	$	818	$	808	$	1,714	$	1,731	$	748		$	818	$	1,637		$	1,714
Commercial		546		681		1,160		1,317		564			546		1,111			1,160
Industrial		89		118		186		230		83			89		174			186
Government and other retail		177		197		380		401		208			177		384			380
Wholesale		21		29		45		66		22			21		48			45
Other regulated revenues		94		62		156		88		71			94		128			156
Other nonregulated revenues⁽¹⁾⁽²⁾		20		19		33		33
Other nonregulated revenues⁽¹⁾⁽⁴⁾										27			20		48			33
Total operating revenue from contracts with customers		1,765		1,914		3,674		3,866		1,723			1,765		3,530			3,674
Other revenues⁽²⁾⁽³⁾		40		24		61		37
Other revenues⁽²⁾⁽⁴⁾										18			40		41			61
Total operating revenue	$	1,805	$	1,938	$	3,735	$	3,903	$	1,741		$	1,805	$	3,571		$	3,735
Dominion Energy Gas
Regulated gas sales - wholesale	$	—	$	—	$	2	$	2
Nonregulated gas sales⁽²⁾		—		1		1		3
Regulated gas transportation and storage⁽²⁾		302		306		646		646
Nonregulated gas transportation and storage		175		173		350		348
Management service revenue⁽²⁾		29		45		60		88
Other regulated revenues⁽¹⁾		2		3		3		6
Other nonregulated revenues⁽¹⁾⁽²⁾		1		1		2		1
Total operating revenue from contracts with customers		509		529		1,064		1,094
Other revenues⁽²⁾		1		1		2		2
Total operating revenue	$	510	$	530	$	1,066	$	1,096

1)(1)

~~Amounts above include~~Includes sales which are considered to be goods transferred at a point in ~~time. Such amounts included $19~~time of $8 million and $—$4 million for the three months ended June 30, 2021 and 2020, ~~$42~~respectively, and $15 million and ~~$2 million for the three months ended June 30, 2019, $58 million and $1~~$11 million for the six months ended June 30, 2021 and 2020, respectively, at Dominion Energy, primarily consisting of sales of commodities related to nonregulated extraction activities and other miscellaneous products. Additionally, sales of renewable energy credits were $7 million for both the three months ended June 30, 2021 and 2020, and ~~$93~~$13 million and $3$11 million for the six months ended June 30, ~~2019, primarily consisting of NGL sales~~2021 and 2020, respectively, at Dominion Energy and ~~Dominion Energy Gas, respectively. Additionally, amounts above include sales of renewable energy credits. Such amounts included $7 million and~~ $5 million for both the three months ended June 30, 2021 and 2020, ~~$4 million~~ and ~~$2 million for the three months ended June 30, 2019, $11~~$9 million and $8 million for the six months ended June 30, 2021 and 2020, respectively, at Virginia Power.

(2)

Includes alternative revenue of $25 million and $7$39 million at Dominion Energy and $18 million and $34 million at Virginia Power for the three months ended June 30, 2021 and 2020, respectively, and $47 million and $75 million at Dominion Energy and $38 million and $51 million at Virginia Power for the six months ended June 30, 2021 and 2020, respectively.

(3)

Includes revenue associated with services provided to discontinued operations of $1 million and $1 million for the three months ended June 30, 2021 and 2020, respectively, and $2 million and $3 million for the six months ended June 30, ~~2019, at Dominion Energy~~2021 and ~~Virginia Power, respectively.~~

2)	~~See Notes 10 and 19 for amounts attributable to related parties and affiliates.~~

~~Amounts above include alternative revenue of $39 million and $21 million at Dominion Energy and $34 million and $18 million at Virginia Power for the three months ended June 30,~~ 2020, ~~and 2019, respectively, and $75 million and $35 million at Dominion Energy and $51 million and $26 million at Virginia Power for the six months ended June 30, 2020 and 2019,~~ respectively.

(4) See Note 19 for amounts attributable to affiliates.

The table below discloses the aggregate amount of the transaction price allocated to fixed-price performance obligations that are unsatisfied (or partially unsatisfied) at the end of the reporting period and when the Companies expect to recognize this revenue. These revenues relate to contracts containing fixed prices where the Companies will earn the associated revenue over time as they stand ready to perform services provided. This disclosure does not include revenue related to performance obligations that are part of a contract with original durations of one year or less. In addition, this disclosure does not include expected consideration related to performance obligations for which the Companies elect to recognize revenue in the amount they have a right to invoice.

Revenue expected to be recognized on multi-year
contracts in place at June 30, 2020

2020

2021

2022

2023

2024

Thereafter

Total

(millions)

Dominion Energy

$
823

$
1,567

$
1,475

$
1,315

$
1,190

$
13,095

$
19,465

Virginia Power

2

1

—

—

—

—

3

Dominion Energy Gas

899

1,719

1,585

1,402

1,248

13,280

20,133

Revenue expected to be recognized on multi-year

contracts in place at June 30, 2021

2021

2022

2023

2024

2025

Thereafter

Total

(millions)

Dominion Energy

493

771

~~Contract assets represent an entity’s right to consideration in exchange for goods and services that the entity has transferred to a customer.~~ At June 30, ~~2020~~2021 and December 31, ~~2019, Dominion Energy’s contract asset balances were $25 million and $28 million, respectively. Dominion Energy Gas’ contract asset balances were $35 million and $40 million at June 30,~~ 2020, and December 31, 2019, respectively. Dominion Energy and Dominion Energy Gas’ contract assets are recorded in other deferred charges and other assets in the Consolidated Balance Sheets. Contract liabilities represent an entity’s obligation to transfer goods or services to a customer for which the entity has received consideration, or the amount that is due, from the customer. At June 30, 2020 and December 31, 2019, Dominion Energy’s contract liability balances were ~~$109~~$91 million and ~~$123~~$130 million, ~~respectively. At June 30, 2020~~respectively, and December 31, 2019, Virginia Power’s contract liability balances were $37 million and $24 million, respectively. At June 30, 2020 and December 31, 2019, Dominion Energy Gas’ contract liability balances were $21 million and $20 million, respectively. The Companies’ contract liabilities are recorded in other current liabilities and other deferred credits and other liabilities in the Consolidated Balance Sheets. At June 30, 2021 and December 31, 2020, Virginia Power’s contract liability balances were $43 million and $36 million, respectively, and are recorded in other current liabilities and other deferred credits and other liabilities in its Consolidated Balance Sheets.

The Companies recognize revenue as they fulfill their obligations to provide service to their customers. During the six months ended June 30, ~~2020~~2021 and ~~2019~~2020, Dominion Energy recognized revenue of ~~$106~~$123 million and ~~$91~~$106 million, respectively, from the beginning contract liability balances. During the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, Virginia Power recognized ~~$24~~$36 million and ~~$22~~$24 million, respectively, from the beginning contract liability balance. ~~During the six months ended June 30, 2020 and 2019, Dominion Energy Gas recognized $1 million and $28 million from the beginning contract liability balance.~~

Note 5. Income Taxes

For continuing operations, including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to the Companies’ effective income tax rate as follows:

	Dominion Energy						Virginia Power						Dominion Energy Gas								Dominion Energy						Virginia Power
Six Months Ended June 30,	2020			2019			2020			2019			2020				2019				2021			2020			2021			2020
U.S. statutory rate		21.0	%		21.0	%		21.0	%		21.0	%		21.0	%			21.0	%			21.0	%		21.0	%		21.0	%		21.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit		5.6			0.7			4.9			4.7			(255.3	)			3.0				2.3			4.1			4.5			4.9
Investment tax credits		3.9			(3.8	)		(11.3	)		(5.2	)		—				—				(5.3	)		(19.5	)		(5.8	)		(11.3	)
Production tax credits		0.3			(1.1	)		(2.0	)		(0.8	)		—				—				(0.4	)		(1.6	)		(0.6	)		(2.0	)
Reversal of excess deferred income taxes		1.5			(6.9	)		(0.8	)		(4.2	)		(68.4	)			(0.9	)			(3.5	)		(6.5	)		(2.1	)		(0.8	)
Write-off of regulatory assets		(4.2	)		(41.6	)		—			—			189.4				—
State legislative change																						(1.5	)		—			(1.7	)		—
AFUDC - equity		0.5			(1.9	)		(0.6	)		(0.1	)		(36.8	)			(0.5	)			(0.5	)		(2.1	)		(0.6	)		(0.6	)
Other, net		0.9			(0.3	)		1.1			0.4			(467.1	)	⁽¹⁾		(4.3	)	⁽¹⁾		(0.4	)		1.2			0.3			1.1
Effective tax rate		29.5	%		(33.9	)%		12.3	%		15.8	%		(617.2	)%			18.3	%			11.7	%		(3.4	)%		15.0	%		12.3	%

~~(1)~~

~~Includes (276.0)% and (4.0)% relating to the absence of tax on noncontrolling interest in 2020 and 2019, respectively~~.

For the Companies’ rate-regulated entities, deferred taxes will reverse at the weighted average rate used to originate the deferred tax liability, which in some cases will be 35%. The Companies have recorded an estimate of excess deferred income tax amortization in ~~2020.~~2021. The reversal of these excess deferred income taxes will impact the effective tax rate and rates charged to customers. See Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019~~2020 for more information.

For the six months ended June 30, 2020, Dominion Energy’s effective tax rate reflects a charge of $81 million for the write-off of tax-related regulatory assets associated with the impacts of the cancellation of the Atlantic Coast Pipeline Project and related portions of the Supply Header Project. In addition, Dominion Energy Gas’ effective tax rate is a function of the nominal year-to-date pre-tax income driven by a charge associated with the Supply Header Project as discussed in Note 2.

In March 2020, the CARES Act was enacted which includes several significant business tax provisions that modify or temporarily suspend certain provisions of the 2017 Tax Reform Act. The CARES Act provisions are intended to improve cash flow and liquidity by, among other things, providing a temporary five-year carryback for certain net operating losses, accelerating the refund of previously generated corporate alternative minimum tax credits and temporarily loosening the business interest limitation to 50% of adjusted taxable income for certain businesses. While Dominion Energy intends to utilize the income tax provisions of the CARES Act to accelerate the recognition of certain tax attributes, where applicable, they are not expected to provide a material benefit.

In July 2020, the U.S. Department of Treasury issued final regulations providing guidance about the limitation on the deduction for business interest expenses and issued proposed regulations on the application of these rules to certain pass-through entities and partners in those entities under the 2017 Tax Reform Act as modified by the CARES Act. Dominion Energy is currently assessing the impact of these regulations, but expects interest expense to be deductible in 2020.

In connection with the SCANA Combination, Dominion Energy committed to forgo, or limit, the recovery of certain income tax-related regulatory assets associated with the NND Project. Dominion Energy’s 2019 effective tax rate reflects deferred income tax expense of $198 million in satisfaction of this commitment. Dominion Energy’s 2019 effective tax rate also reflects the changes in consolidated state income taxes resulting from the SCANA Combination.

As of June 30, ~~2020,~~2021, there have been no material changes in the Companies’ unrecognized tax benefits or possible changes that could reasonably be expected to occur during the next twelve months. See Note 5 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019,~~2020, for a discussion of these unrecognized tax benefits.

The Companies’ effective tax rates reflect the benefit of a state legislative change enacted in April 2021 for tax years beginning January 1, 2022. Dominion Energy’s effective tax rate reflects a $21 million deferred tax benefit, inclusive of a $16 million deferred tax benefit at Virginia Power.

Discontinued operations

Income tax expense (benefit) included in discontinued operations is $11 million and $(562) million for the six months ended June 30, 2021 and 2020, respectively. 2020 income taxes reflect a charge of $81 million for the write-off of tax-related regulatory assets associated with the Atlantic Coast Pipeline Project.

Note 6. Earnings Per Share

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

Three Months Ended June 30,

Six Months Ended June 30,

2020

2019

2020

2019

(millions, except EPS)

Net income (loss) attributable to Dominion Energy

$
(1,169
)

$
54

$
(1,439
)

$
(626
)
Preferred stock dividends (see Note 16)

(16
)

—

(32
)

—

Net income (loss) attributable to Dominion Energy – Basic

(1,185
)

54

(1,471
)

(626
)
Dilutive effect of Series A Preferred Stock

—

(13
)

—

—

Net income (loss) attributable to Dominion Energy - Diluted

(1,185
)

41

(1,471
)

(626
)
Average shares of common stock outstanding – Basic &
Diluted

839.4

802.5

838.8

797.8

Net effect of dilutive securities

—

0.1

—

—

Average shares of common stock outstanding – Diluted

839.4

802.6

838.8

797.8

Earnings Per Common Share – Basic

$
(1.41
)

$
0.07

$
(1.75
)

$
(0.78
)
Earnings Per Common Share – Diluted

$
(1.41
)

$
0.05

$
(1.75
)

$
(0.78
)

	Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020
(millions, except EPS)
Net income attributable to Dominion Energy from continuing operations	$	259		$	863		$	1,239		$	397
Preferred stock dividends (see Note 16)		(16	)		(16	)		(32	)		(32	)
Net income attributable to Dominion Energy from continuing operations – Basic		243			847			1,207			365
Dilutive effect of Series A Preferred Stock		—			(92	)		—			(64	)
Net income attributable to Dominion Energy from continuing operations - Diluted	$	243		$	755		$	1,207		$	301
Net income (loss) attributable to Dominion Energy from discontinued operations - Basic & Diluted	$	26		$	(2,032	)	$	54		$	(1,836	)
Average shares of common stock outstanding – Basic		806.6			839.4			806.2			838.8
Net effect of dilutive securities		—			—			0.1			—
Average shares of common stock outstanding – Diluted		806.6			839.4			806.3			838.8

EPS from continuing operations – Basic	$	0.30		$	1.01		$	1.49		$	0.43
EPS from discontinued operations – Basic		0.03			(2.42	)		0.07			(2.18	)
EPS attributable to Dominion Energy – Basic	$	0.33		$	(1.41	)	$	1.56		$	(1.75	)

EPS from continuing operations – Diluted	$	0.30		$	0.90		$	1.49		$	0.35
EPS from discontinued operations – Diluted		0.03			(2.42	)		0.07			(2.18	)
EPS attributable to Dominion Energy – Diluted	$	0.33		$	(1.52	)	$	1.56		$	(1.83	)

As a result of a net loss for the three and six months ended June 30, 2020 and the six months ended June 30, 2019, any adjustments to earnings or shares would be considered antidilutive and are therefore excluded from the calculation of diluted EPS. The 2019 Equity Units and the Q-Pipe Transaction deposit, prior to being settled in cash in July 2021, are potentially dilutive securities. See Note 19 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2020 and Note 3, respectively, for additional information. The forward stock purchase contracts included within the 2019 Equity Units were excluded from the calculation of diluted EPS from continuing operations for the three and six months ended June 30, ~~2019,~~2021 and 2020, as the dilutive stock price threshold was not met. The Series A Preferred Stock included within the 2019 Equity Units is excluded from the ~~effect of dilutive securities within diluted EPS, but a fair value adjustment is reflected within net income attributable to Dominion Energy for the~~ calculation of diluted EPS ~~for the three months ended June 30, 2019,~~from continuing operations based upon the expectation that the conversion will be settled in cash rather than through the

issuance of Dominion Energy common stock. ~~The 2016~~For the three and six months ended June 30, 2021, a fair value adjustment related to the Series A Preferred Stock included within the 2019 Equity Units ~~are potentially dilutive securities, but were~~is excluded from the calculation of diluted EPS from continuing operations, as such fair value adjustment was not dilutive during the periods. The impact of settling the deposit associated with the Q-Pipe Transaction in shares is excluded from the calculation of diluted EPS from continuing operations for the three and six months ended June 30, ~~2019 as~~2021 based upon the ~~dilutive stock price threshold was not met.~~expectation Dominion Energy would settle in cash rather than through the issuance of Dominion Energy common stock.

Note 7. Accumulated Other Comprehensive Income (Loss)

Dominion Energy

The following table presents Dominion Energy’s changes in AOCI by component, net of tax:

	Deferred gains and losses on derivatives- hedging activities			Unrealized gains and losses on investment securities			Unrecognized pension and other postretirement benefit costs			Other comprehensive loss from equity method investees			Total			Deferred gains and losses on derivatives- hedging activities			Unrealized gains and losses on investment securities			Unrecognized pension and other postretirement benefit costs			Other comprehensive loss from equity method investees			Total
(millions)
Three Months Ended June 30, 2021
Beginning balance																$	(367	)	$	32		$	(1,335	)	$	(1	)	$	(1,671	)
Other comprehensive income before reclassifications: gains (losses)																	(16	)		12			—			0			(4	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾																	12			(3	)		26			0			35
Net current period other comprehensive income (loss)																	(4	)		9			26			0			31
Ending balance																$	(371	)	$	41		$	(1,309	)	$	(1	)	$	(1,640	)
Three Months Ended June 30, 2020
Beginning balance	$	(651	)	$	37		$	(1,402	)	$	(2	)	$	(2,018	)	$	(651	)	$	37		$	(1,402	)	$	(2	)	$	(2,018	)
Other comprehensive income before reclassifications: gains (losses)		2			19			(1	)		—			20			2			19			(1	)		0			20
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		5			(5	)		18			—			18			5			(5	)		18			0			18
Net current period other comprehensive income (loss)		7			14			17			—			38			7			14			17			0			38
Ending balance	$	(644	)	$	51		$	(1,385	)	$	(2	)	$	(1,980	)	$	(644	)	$	51		$	(1,385	)	$	(2	)	$	(1,980	)
Three Months Ended June 30, 2019
Six Months Ended June 30, 2021
Beginning balance	$	(290	)	$	18		$	(1,457	)	$	(2	)	$	(1,731	)	$	(419	)	$	62		$	(1,359	)	$	(1	)	$	(1,717	)
Other comprehensive income before reclassifications: gains (losses)		(78	)		13			113			—			48			23			(19	)		6			0			10
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(21	)		(1	)		22			—			—			25			(2	)		44			0			67
Net current period other comprehensive income (loss)		(99	)		12			135			—			48			48			(21	)		50			0			77
Ending balance	$	(389	)	$	30		$	(1,322	)	$	(2	)	$	(1,683	)	$	(371	)	$	41		$	(1,309	)	$	(1	)	$	(1,640	)
Six Months Ended June 30, 2020
Beginning balance	$	(407	)	$	37		$	(1,421	)	$	(2	)	$	(1,793	)	$	(407	)	$	37		$	(1,421	)	$	(2	)	$	(1,793	)
Other comprehensive income before reclassifications: gains (losses)		(264	)		28			(1	)		—			(237	)		(264	)		28			(1	)		0			(237	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		27			(14	)		37			—			50			27			(14	)		37			0			50
Net current period other comprehensive income (loss)		(237	)		14			36			—			(187	)		(237	)		14			36			0			(187	)
Ending balance	$	(644	)	$	51		$	(1,385	)	$	(2	)	$	(1,980	)	$	(644	)	$	51		$	(1,385	)	$	(2	)	$	(1,980	)
Six Months Ended June 30, 2019
Beginning balance	$	(235	)	$	2		$	(1,465	)	$	(2	)	$	(1,700	)
Other comprehensive income before reclassifications: gains (losses)		(102	)		29			113			—			40
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(52	)		(1	)		30			—			(23	)
Net current period other comprehensive income (loss)		(154	)		28			143			—			17
Ending balance	$	(389	)	$	30		$	(1,322	)	$	(2	)	$	(1,683	)

(1)	See table below for details about these reclassifications.

The following table presents Dominion Energy’s reclassifications out of AOCI by component:

Details about AOCI components

Amounts
reclassified
from AOCI

Affected line item in the
Consolidated Statements of
Income
(millions)

Three Months Ended June 30, 2020

Deferred (gains) and losses on derivatives-hedging activities:

Commodity contracts

$
(9
)

Operating revenue
Interest rate contracts

22

Interest and related charges
Foreign currency contracts

(6
)

Other income
Total

7

Tax

(2
)

Income tax expense (benefit)
Total, net of tax

$
5

Unrealized (gains) and losses on investment securities:

Realized (gains) losses on sale of securities

$
(5
)

Other income
Total

(5
)

Tax

—

Income tax expense (benefit)
Total, net of tax

$
(5
)

Unrecognized pension and other postretirement benefit costs:

Amortization of prior-service costs (credits)

$
(5
)

Other income
Amortization of actuarial losses

31

Other income
Total

26

Tax

(8
)

Income tax expense (benefit)
Total, net of tax

$
18

Three Months Ended June 30, 2019

Deferred (gains) and losses on derivatives-hedging activities:

Commodity contracts

$
(38
)

Operating revenue
Interest rate contracts

13

Interest and related charges
Foreign currency contracts

(4
)

Other income
Total

(29
)

Tax

8

Income tax expense (benefit)
Total, net of tax

$
(21
)

Unrealized (gains) and losses on investment securities:

Realized (gains) losses on sale of securities

$
(1
)

Other income
Total

(1
)

Tax

—

Income tax expense (benefit)
Total, net of tax

$
(1
)

Unrecognized pension and other postretirement benefit costs:

Amortization of prior-service costs (credits)

$
(8
)

Other income
Amortization of actuarial losses

27

Other income
Total

19

Tax

3

Income tax expense (benefit)
Total, net of tax

$
22

Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Three Months Ended June 30, 2021
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts	$	16		Interest and related charges
Total		16
Tax		(4	)	Income tax expense (benefit)
Total, net of tax	$	12
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities	$	(4	)	Other income
Total		(4	)
Tax		1		Income tax expense (benefit)
Total, net of tax	$	(3	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(5	)	Other income
Amortization of actuarial losses		40		Other income
Total		35
Tax		(9	)	Income tax expense (benefit)
Total, net of tax	$	26
Three Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(8	)	Operating revenue
		(1	)	Discontinued operations
Interest rate contracts		18		Interest and related charges
		4		Discontinued operations
Foreign currency contracts		(6	)	Discontinued operations
Total		7
Tax		(2	)	Income tax expense (benefit)
Total, net of tax	$	5
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities	$	(5	)	Other income (expense)
Total		(5	)
Tax		—		Income tax expense (benefit)
Total, net of tax	$	(5	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(5	)	Other income (expense)
Amortization of actuarial losses		31		Other income (expense)
Total		26
Tax		(8	)	Income tax expense (benefit)
Total, net of tax	$	18

Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Six Months Ended June 30, 2021
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	1		Purchased gas
Interest rate contracts		32		Interest and related charges
Total		33
Tax		(8	)	Income tax expense (benefit)
Total, net of tax	$	25
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities	$	(3	)	Other income

Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Total						(3	)
Tax						1		Income tax expense (benefit)
Total, net of tax					$	(2	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)					$	(10	)	Other income
Amortization of actuarial losses						70		Other income
Total						60
Tax						(16	)	Income tax expense (benefit)
Total, net of tax					$	44
Six Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(16	)	Operating revenue	$	(14	)	Operating revenue
		3		Purchased gas		3		Purchased gas
						(2	)	Discontinued operations
Interest rate contracts		49		Interest and related charges		43		Interest and related charges
						6		Discontinued operations
Total		36				36
Tax		(9	)	Income tax expense (benefit)		(9	)	Income tax expense (benefit)
Total, net of tax	$	27			$	27
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities	$	(18	)	Other income	$	(18	)	Other income (expense)
Total		(18	)			(18	)
Tax		4		Income tax expense (benefit)		4		Income tax expense (benefit)
Total, net of tax	$	(14	)		$	(14	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(11	)	Other income	$	(11	)	Other income (expense)
Amortization of actuarial losses		61		Other income		61		Other income (expense)
Total		50				50
Tax		(13	)	Income tax expense (benefit)		(13	)	Income tax expense (benefit)
Total, net of tax	$	37			$	37
Six Months Ended June 30, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(92	)	Operating revenue
		(3	)	Purchased gas
Interest rate contracts		23		Interest and related charges
Foreign currency contracts		2		Other income
Total		(70	)
Tax		18		Income tax expense (benefit)
Total, net of tax	$	(52	)
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities	$	(1	)	Other income
Total		(1	)
Tax		—		Income tax expense (benefit)
Total, net of tax	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(13	)	Other income
Amortization of actuarial losses		54		Other income
Total		41
Tax		(11	)	Income tax expense (benefit)
Total, net of tax	$	30

Virginia Power

The following table presents Virginia Power’s changes in AOCI by component, net of tax:

Deferred gains
and losses on
derivatives-
hedging
activities

Unrealized gains
and losses on
investment
securities

Total

(millions)

Three Months Ended June 30, 2020

Beginning balance

$
(79
)

$
4

$
(75
)
Other comprehensive income before reclassifications:
   gains (losses)

1

6

7

Amounts reclassified from AOCI: (gains) losses⁽¹⁾

—

(2
)

(2
)
Net current period other comprehensive income (loss)

1

4

5

Ending balance

$
(78
)

$
8

$
(70
)
Three Months Ended June 30, 2019

Beginning balance

$
(20
)

$
3

$
(17
)
Other comprehensive income before reclassifications:
   gains (losses)

(11
)

2

(9
)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾

1

(1
)

—

Net current period other comprehensive income (loss)

(10
)

1

(9
)
Ending balance

$
(30
)

$
4

$
(26
)
Six Months Ended June 30, 2020

Beginning balance

$
(34
)

$
5

$
(29
)
Other comprehensive income before reclassifications:
   gains (losses)

(44
)

4

(40
)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾

—

(1
)

(1
)
Net current period other comprehensive income (loss)

(44
)

3

(41
)
Ending balance

$
(78
)

$
8

$
(70
)
Six Months Ended June 30, 2019

Beginning balance

$
(13
)

$
1

$
(12
)
Other comprehensive income before reclassifications:
   gains (losses)

(18
)

4

(14
)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾

1

(1
)

—

Net current period other comprehensive income (loss)

(17
)

3

(14
)
Ending balance

$
(30
)

$
4

$
(26
)

~~(1)~~

~~See table below for details about these reclassifications. Virginia Power’s reclassifications out of AOCI were immaterial for both the three and six months ended June 30, 2019.~~

~~The following table presents Virginia Power’s reclassifications out of AOCI by component:~~

Details about AOCI components

Amounts
reclassified
from AOCI

Affected line item in the
Consolidated Statements of
Income
(millions)

Three Months Ended June 30, 2020

(Gains) losses on cash flow hedges:

Interest rate contracts

$
1

Interest and related charges
Total

1

Tax

(1
)

Income tax expense
Total, net of tax

$
—

Unrealized (gains) and losses on investment securities:

Realized (gains) losses on sale of securities

$
(4
)

Other income
Total

(4
)

Tax

2

Income tax expense
Total, net of tax

$
(2
)

Six Months Ended June 30, 2020

(Gains) losses on cash flow hedges:

Interest rate contracts

1

Interest and related charges
Total

1

Tax

(1
)

Income tax expense
Total, net of tax

$
—

Unrealized (gains) and losses on investment securities:

Realized (gains) losses on sale of securities

$
(2
)

Other income
Total

(2
)

Tax

1

Income tax expense
Total, net of tax

$
(1
)

~~Dominion Energy Gas~~

~~The following table presents Dominion Energy Gas’ changes in AOCI by component, net of tax:~~

	Deferred gains and losses on derivatives- hedging activities			Unrecognized pension costs			Total			Deferred gains and losses on derivatives- hedging activities			Unrealized gains and losses on investment securities			Total
(millions)
Three Months Ended June 30, 2020
Three Months Ended June 30, 2021
Beginning balance	$	(166	)	$	(105	)	$	(271	)	$	(27	)	$	4		$	(23	)
Other comprehensive income before reclassifications: gains (losses)											(12	)		3			(9	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(2	)		2			—			—			(1	)		(1	)
Net current period other comprehensive income (loss)		(2	)		2			—			(12	)		2			(10	)
Ending balance	$	(168	)	$	(103	)	$	(271	)	$	(39	)	$	6		$	(33	)
Three Months Ended June 30, 2019
Three Months Ended June 30, 2020
Beginning balance										$	(79	)	$	4		$	(75	)
Other comprehensive income before reclassifications: losses											1			6			7
Amounts reclassified from AOCI: (gains) losses⁽¹⁾											—			(2	)		(2	)
Net current period other comprehensive income (loss)											1			4			5
Ending balance										$	(78	)	$	8		$	(70	)
Six Months Ended June 30, 2021
Beginning balance	$	(48	)	$	(143	)	$	(191	)	$	(60	)	$	8		$	(52	)
Other comprehensive income before reclassifications: gains (losses)		(24	)		29			5			20			(2	)		18
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(2	)		2			—			1			—			1
Net current period other comprehensive income (loss)		(26	)		31			5			21			(2	)		19
Ending balance	$	(74	)	$	(112	)	$	(186	)	$	(39	)	$	6		$	(33	)
Six Months Ended June 30, 2020
Beginning balance	$	(81	)	$	(106	)	$	(187	)	$	(34	)	$	5		$	(29	)
Other comprehensive income before reclassifications: gains (losses)		(91	)		—			(91	)		(44	)		4			(40	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		4			3			7			—			(1	)		(1	)
Net current period other comprehensive income (loss)		(87	)		3			(84	)		(44	)		3			(41	)
Ending balance	$	(168	)	$	(103	)	$	(271	)	$	(78	)	$	8		$	(70	)
Six Months Ended June 30, 2019
Beginning balance	$	(25	)	$	(144	)	$	(169	)
Other comprehensive income before reclassifications: gains (losses)		(51	)		29			(22	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		1			3			4
Net current period other comprehensive income (loss)		(50	)		32			(18	)
Less other comprehensive income (loss) attributable to noncontrolling interest		(1	)		—			(1	)
Ending balance	$	(74	)	$	(112	)	$	(186	)

(1)	See table below for details about these reclassifications.

The following table presents ~~Dominion Energy Gas’~~Virginia Power’s reclassifications out of AOCI by component:

Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Three Months Ended June 30, 2021
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities					$	(1	)	Other income
Total						(1	)
Tax						—		Income tax expense
Total, net of tax					$	(1	)
Three Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts	$	4		Interest and related charges	$	1		Interest and related charges
Foreign currency contracts		(6	)	Other income
Total		(2	)			1
Tax		—		Income tax expense (benefit)		(1	)	Income tax expense (benefit)
Total, net of tax	$	(2	)		$	—
Unrecognized pension and other postretirement benefit costs:
Actuarial losses	$	2		Other income
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities					$	(4	)	Other income (loss)
Total		2				(4	)
Tax		—		Income tax expense (benefit)		2		Income tax expense (benefit)
Total, net of tax	$	2			$	(2	)
Three Months Ended June 30, 2019
Six Months Ended June 30, 2021
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts	$	2		Interest and related charges	$	1		Interest and related charges
Foreign currency contracts		(4	)	Other income
Total		(2	)
Tax		—		Income tax expense (benefit)
Total, net of tax	$	(2	)
Unrecognized pension and other postretirement benefit costs:
Actuarial losses	$	2		Other income
Total		2				1
Tax		—		Income tax expense (benefit)		—		Income tax expense
Total, net of tax	$	2			$	1
Six Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts	$	6		Interest and related charges	$	1		Interest and related charges
Total		6				1
Tax		(2	)	Income tax expense (benefit)		(1	)	Income tax expense (benefit)
Total, net of tax	$	4			$	—
Unrecognized pension and other postretirement benefit costs:
Actuarial losses	$	4		Other income
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities					$	(2	)	Other income (loss)
Total		4				(2	)
Tax		(1	)	Income tax expense (benefit)		1		Income tax expense (benefit)
Total, net of tax	$	3			$	(1	)
Six Months Ended June 30, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(2	)	Net income from discontinued operations
Interest rate contracts		1		Interest and related charges
Foreign currency contracts		2		Other income
Total		1
Tax		—		Income tax expense (benefit)
Total, net of tax	$	1
Unrecognized pension and other postretirement benefit costs:
Actuarial losses	$	4		Other income
Total		4
Tax		(1	)	Income tax expense (benefit)
Total, net of tax	$	3

Note 8. Fair Value Measurements

The Companies’ fair value measurements are made in accordance with the policies discussed in Note 6 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020. See Note 9 in this report for further information about the Companies’ derivatives and hedge accounting activities.

The Companies enter into certain physical and financial forwards, futures, options and swaps, 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, futures and swaps contracts. An option model is used to value Level 3 physical options. The discounted cash flow model for forwards, futures and swaps calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return and credit spreads. The option model calculates mark-to-market valuations using variations of the Black-Scholes option model. The inputs into the 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 and implied price volatilities are considered unobservable.

The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at June 30, ~~2020.~~2021. The range and weighted average are presented in dollars for market price inputs and percentages for price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average⁽¹⁾			Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average⁽¹⁾
Assets
Physical and financial forwards:
Natural gas⁽²⁾	$	112	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 3		(1	)	$	53	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 4		(1	)
FTRs		18	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 5		1			30	Discounted cash flow	Market price (per MWh)	⁽³⁾	0 - 6		1
Total assets	$	130
Liabilities
Financial forwards:
FTRs	$	5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(5) - 5		—
Electricity											12	Discounted cash flow	Market price (per MWh)	⁽³⁾	22 - 83		35
Physical options:
Natural gas		2	Option model	Market price (per Dth)	⁽³⁾	1 - 5		2			1	Option model	Market price (per Dth)	⁽³⁾	2 - 7		4
				Price volatility	⁽⁴⁾	56% - 72%		66	%				Price volatility	⁽⁴⁾	4% - 27%		16	%
Total assets										$	96
Liabilities
Physical and financial forwards:
Natural gas⁽²⁾										$	7	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 3		(1	)
FTRs											3	Discounted cash flow	Market price (per MWh)	⁽³⁾	(3) - 4		1
Electricity											24	Discounted cash flow	Market price (per MWh)	⁽³⁾	23 - 96		35
Total liabilities	$	7								$	34

(1)	Averages weighted by volume.

(2)	Includes basis.

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

~~(4)~~

~~Represents volatilities unrepresented in published markets.~~

(4) 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)
Price volatility	Buy	Increase (decrease)	Gain (loss)
Price volatility	Sell	Increase (decrease)	Loss (gain)

Nonrecurring Fair Value Measurements

In the second quarter of 2021, Dominion Energy recorded a charge of $20 million ($15 million after-tax) in impairment of assets and other charges in its Consolidated Statements of Income to write off substantially all of the long-lived assets of its nonregulated retail software development operations to their estimated fair value, using a market approach, of less than $1 million. The valuation is considered a Level 2 fair value measurement given that it is based on bids received.

See Note 3 for information on the nonrecurring fair value measurement associated with the acquisition of Birdseye.

Recurring Fair Value Measurements

Dominion Energy

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

	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
(millions)
At June 30, 2020
At June 30, 2021
Assets
Derivatives:
Commodity									$	0	$	52	$	96	$	148
Interest rate										0		468		0		468
Investments⁽¹⁾:
Equity securities:
U.S.										4,730		0		0		4,730
Fixed income:
Corporate debt instruments										0		871		0		871
Government securities										783		744		0		1,527
Total assets									$	5,513	$	2,135	$	96	$	7,744
Liabilities
Derivatives:
Commodity									$	0	$	211	$	34	$	245
Interest rate										0		329		0		329
Total liabilities									$	0	$	540	$	34	$	574
At December 31, 2020													��
Assets
Derivatives:
Commodity	$	—	$	52	$	130	$	182	$	0	$	57	$	110	$	167
Interest rate		—		34		—		34		0		230		0		230
Investments⁽¹⁾:
Equity securities:
U.S.		3,817		—		—		3,817		4,648		0		0		4,648
Fixed income:
Corporate debt instruments		—		624		—		624		0		629		0		629
Government securities		488		746		—		1,234		508		730		0		1,238
Cash equivalents and other		19		12		—		31		32		15		0		47
Total assets	$	4,324	$	1,468	$	130	$	5,922	$	5,188	$	1,661	$	110	$	6,959
Liabilities
Derivatives:
Commodity	$	—	$	43	$	7	$	50	$	0	$	48	$	7	$	55
Interest rate		—		1,272		—		1,272		0		431		0		431
Foreign currency		—		12		—		12
Total liabilities	$	—	$	1,327	$	7	$	1,334	$	0	$	479	$	7	$	486
At December 31, 2019
Assets
Derivatives:
Commodity	$	—	$	55	$	19	$	74
Interest rate		—		11		—		11
Foreign currency		—		8		—		8
Investments⁽¹⁾:
Equity securities:
U.S.		4,195		—		—		4,195
Fixed income:
Corporate debt instruments		—		463		—		463
Government securities		473		719		—		1,192
Cash equivalents and other		19		1		—		20
Total assets	$	4,687	$	1,257	$	19	$	5,963
Liabilities
Derivatives:
Commodity	$	—	$	75	$	56	$	131
Interest rate		—		606		—		606
Foreign currency		—		3		—		3
Total liabilities	$	—	$	684	$	56	$	740

(1)

Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes ~~$296~~$357 million and ~~$274~~$340 million of assets at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, 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.

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

	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Beginning balance	$	43		$	53		$	(37	)	$	64		$	56		$	43		$	103		$	(37	)
Total realized and unrealized gains (losses):
Included in earnings:
Operating revenue		—			3			—			2			(2	)		0			(2	)		0
Purchased gas		—			1			—			1
Electric fuel and other energy-related purchases		(4	)		(3	)		(26	)		(7	)		4			(4	)		(17	)		(26	)
Included in regulatory assets/liabilities		80			18			160			25			8			80			(39	)		160
Settlements		4			3			26			2			(4	)		4			17			26
Purchases		—			—			—			(10	)
Transfers out of Level 3		—			—			—			(2	)
Ending balance	$	123		$	75		$	123		$	75		$	62		$	123		$	62		$	123
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date:
Operating revenue	$	—		$	2		$	—		$	2
Purchased gas		—			1			—			1
Total	$	—		$	3		$	—		$	3

There ~~were no~~are $(2) million of unrealized gains orand losses included in ~~earnings~~operating revenue in the Level 3 fair value category ~~relating~~related to assets/liabilities still held at the reporting date for the three and six months ended June 30, ~~2020~~2021. There were 0 unrealized gains and ~~2019.~~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 six months ended June 30, 2020.

Virginia Power

The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at June 30, ~~2020.~~2021. The range and weighted average are presented in dollars for market price ~~inputs and percentages for price volatility.~~inputs.

	Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average⁽¹⁾			Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average⁽¹⁾
Assets
Physical and financial forwards:
Natural gas⁽²⁾	$	112	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 2		(1	)	$	53	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 4		(1	)
FTRs		18	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 5		1			30	Discounted cash flow	Market price (per MWh)	⁽³⁾	0 - 6		1
Total assets	$	130
Liabilities
Financial forwards:
FTRs	$	5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(5) - 5		—
Physical options:
Natural gas		2	Option model	Market price (per Dth)	⁽³⁾	1 - 5		2			1	Option model	Market price (per Dth)	⁽³⁾	2 - 7		4
				Price volatility	⁽⁴⁾	56% - 72%		66	%				Price volatility	⁽⁴⁾	4% - 27%		16	%
Total assets										$	84
Liabilities
Physical and financial forwards:
Natural gas⁽²⁾										$	7	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 3		(1	)
FTRs											3	Discounted cash flow	Market price (per MWh)	⁽³⁾	(3) - 4		1
Total liabilities	$	7								$	10

(1)	Averages weighted by volume.

(2)	Includes basis.

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

(4)Represents volatilities unrepresented in published markets.

~~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)
Price volatility	Buy	Increase (decrease)	Gain (loss)
Price volatility	Sell	Increase (decrease)	Loss (gain)

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

	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
(millions)
At June 30, 2020
At June 30, 2021
Assets
Derivatives:
Commodity	$	—	$	3	$	130	$	133	$	0	$	27	$	84	$	111
Interest rate										0		172		0		172
Investments⁽¹⁾:
Equity securities:
U.S.		1,787		—		—		1,787		2,186		0		0		2,186
Fixed income:
Corporate debt instruments		—		354		—		354		0		486		0		486
Government securities		184		306		—		490		387		282		0		669
Total assets	$	1,971	$	663	$	130	$	2,764	$	2,573	$	967	$	84	$	3,624
Liabilities
Derivatives:
Commodity	$	—	$	17	$	7	$	24	$	0	$	42	$	10	$	52
Interest rate		—		980		—		980		0		283		0		283
Total liabilities	$	—	$	997	$	7	$	1,004	$	0	$	325	$	10	$	335
At December 31, 2019
At December 31, 2020
Assets
Derivatives:
Commodity	$	—	$	3	$	19	$	22	$	0	$	5	$	110	$	115
Interest rate		—		2		—		2		0		66		0		66
Investments⁽¹⁾:
Equity securities:
U.S.		1,920		—		—		1,920		2,171		0		0		2,171
Fixed income:
Corporate debt instruments		—		256		—		256		0		348		0		348
Government securities		186		361		—		547		201		309		0		510
Cash equivalents and other		—		1		—		1		13		0		0		13
Total assets	$	2,106	$	623	$	19	$	2,748	$	2,385	$	728	$	110	$	3,223
Liabilities
Derivatives:
Commodity	$	—	$	47	$	56	$	103	$	0	$	22	$	7	$	29
Interest rate		—		363		—		363		0		376		0		376
Total liabilities	$	—	$	410	$	56	$	466	$	0	$	398	$	7	$	405

(1)

Includes investments held in the nuclear decommissioning trusts. Excludes ~~$154~~$176 million and ~~$159~~$167 million of assets at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, 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.

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

	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Beginning balance	$	43		$	59		$	(37	)	$	60		$	56		$	43		$	103		$	(37	)
Total realized and unrealized gains (losses):
Included in earnings:
Electric fuel and other energy-related purchases		(4	)		(3	)		(26	)		(7	)		4			(4	)		(17	)		(26	)
Included in regulatory assets/liabilities		80			18			160			26			18			80			(29	)		160
Settlements		4			3			26			(2	)		(4	)		4			17			26
Ending balance	$	123		$	77		$	123		$	77		$	74		$	123		$	74		$	123

There were 0 unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the three and six months ended June 30, ~~2020~~2021 and ~~2019.~~

~~Dominion Energy Gas~~

The following table presents Dominion Energy Gas’ assets and liabilities for derivatives that are measured at fair value on a recurring basis for each hierarchy level, including both current and noncurrent portions.2020.

Level 1

Level 2

Level 3

Total

(millions)

At June 30, 2020

Liabilities

Interest rate

$
—

$
192

$
—

$
192

Foreign currency

—

12

—

12

Total liabilities

$
—

$
204

$
—

$
204

At December 31, 2019

Assets

Foreign currency

$
—

$
8

$
—

$
8

Total assets

$
—

$
8

$
—

$
8

Liabilities

Interest rate

$
—

$
83

$
—

$
83

Foreign currency

—

3

—

3

Total liabilities

$
—

$
86

$
—

$
86

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:

	June 30, 2020				December 31, 2019				June 30, 2021				December 31, 2020
	Carrying Amount		Estimated Fair Value⁽¹⁾		Carrying Amount		Estimated Fair Value⁽¹⁾		Carrying Amount		Estimated Fair Value⁽¹⁾		Carrying Amount		Estimated Fair Value⁽¹⁾
(millions)
Dominion Energy
Long-term debt⁽²⁾⁽³⁾	$	36,060	$	42,151	$	32,055	$	36,155	$	33,076	$	38,558	$	31,996	$	38,773
Supplemental 364-Day credit facility borrowings		225		225		—		—
Supplemental credit facility borrowings⁽⁴⁾										250		250		225		225
Junior subordinated notes⁽³⁾⁽⁵⁾		3,408		3,554		4,797		4,953		2,862		3,024		3,411		3,633
Virginia Power
Long-term debt⁽³⁾⁽⁵⁾	$	12,328	$	15,189	$	12,326	$	14,281	$	13,210	$	15,668	$	13,207	$	16,455
Dominion Energy Gas
Long-term debt⁽⁴⁾	$	5,523	$	5,891	$	5,520	$	5,738

(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 and foreign currency remeasurement adjustments.~~premium. At both June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, the carrying amount includes the valuation of certain fair value hedges associated with fixed rate debt of ~~$4 million and $4 million, respectively.~~$3 million.

(3)	Includes amounts classified as held for sale, see Note 3.

(4)	Also includes Supplemental 364-Day credit facility borrowings.

(5)	Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs, discount or premium.

~~(4)~~

Carrying amount includes current portions included in securities due within one year and amounts which represent the unamortized debt issuance costs, discount or premium and foreign currency remeasurement adjustments.

Note 9. Derivatives and Hedge Accounting Activities

The Companies’ accounting policies, objectives and strategies for using derivative instruments are discussed in Note 2 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020. See Note 8 in this report for further information about fair value measurements and associated valuation methods for derivatives.

Derivative assets and liabilities are presented gross on the Companies’ Consolidated Balance Sheets. ~~Dominion Energy’s~~The Companies’ derivative contracts include both over-the-counter transactions and those that are executed on an exchange or other trading platform (exchange contracts) and centrally cleared. ~~Virginia Power and Dominion Energy Gas’ derivative contracts include over-the-counter transactions.~~ Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Exchange contracts utilize a financial intermediary, exchange, or clearinghouse to enter, execute or clear the transactions. Certain over-the-counter and exchange contracts contain contractual rights of setoff through master netting arrangements, derivative clearing agreements and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency or other conditions.

In general, most over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral for over-the-counter and exchange contracts include cash, letters of credit, and in some cases other forms of ~~security,~~securities, none of which are subject to restrictions. Cash collateral, ~~is used~~as presented in the table below, is used to offset derivative assets and liabilities. Certain accounts receivable and accounts payable recognized on the Companies’ Consolidated Balance Sheets, ~~as well as~~ letters of credit and other forms of ~~security,~~securities, as well as certain long-term debt, all of which are not included in the tables below, are subject to offset under master netting or similar arrangements and would reduce the net exposure. See Note 18 for further information regarding credit-related contingent features for the Companies’ derivative instruments.

Dominion Energy

Balance Sheet Presentation

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

	June 30, 2020								December 31, 2019								June 30, 2021								December 31, 2020
	Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								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		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)
Commodity contracts:
Over-the-counter	$	136	$	9	$	—	$	127	$	35	$	21	$	—	$	14	$	114	$	13	$	0	$	101	$	117	$	9	$	0	$	108
Exchange		45		20		7		18		37		21		—		16		22		18		0		4		49		24		0		25
Interest rate contracts:
Over-the-counter		34		14		—		20		11		3		—		8		468		26		0		442		230		13		0		217
Foreign currency contracts:
Over-the-counter		—		—		—		—		8		8		—		—
Total derivatives, subject to a master netting or similar arrangement	$	215	$	43	$	7	$	165	$	91	$	53	$	—	$	38	$	604	$	57	$	0	$	547	$	396	$	46	$	0	$	350

(1)	Excludes $1$12 million and $2$1 million of derivative assets at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, which are not subject to master netting or similar arrangements.

	June 30, 2020								December 31, 2019								June 30, 2021								December 31, 2020
	Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								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		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)
Commodity contracts:
Over-the-counter	$	30	$	9	$	—	$	21	$	105	$	21	$	—	$	84	$	49	$	13	$	9	$	27	$	30	$	9	$	0	$	21
Exchange		20		20		—		—		21		21		—		—		168		18		150		0		24		24		0		0
Interest rate contracts:
Over-the-counter		1,272		14		22		1,236		606		8		35		563		329		26		11		292		431		13		17		401
Foreign currency contracts:
Over-the-counter		12		—		—		12		3		3		—		—
Total derivatives, subject to a master netting or similar arrangement	$	1,334	$	43	$	22	$	1,269	$	735	$	53	$	35	$	647	$	546	$	57	$	170	$	319	$	485	$	46	$	17	$	422

(1)	Excludes $—$28 million and $5$1 million of derivative liabilities at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, which are not subject to master netting or similar arrangements.

Volumes

The following table presents the volume of Dominion Energy’s derivative activity at June 30, ~~2020.~~2021. 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 its long and short positions.

	Current		Noncurrent		Current		Noncurrent
Natural Gas (bcf):
Fixed price⁽¹⁾		69		32		59		14
Basis		236		538		202		471
Electricity (MWh):
Fixed price		4,964,045		2,775,850		12,116,472		30,423,292
FTRs		101,087,887		—		98,414,736		0
Liquids (Gal)⁽²⁾		26,460,000		—
Interest rate⁽³⁾	$	1,950,000,000	$	6,576,403,434
Foreign currency⁽³⁾	€	-	€	250,000,000
Interest rate⁽²⁾ (millions)					$	1,250	$	8,000

(1)	Includes options.

(2)	~~Includes NGLs.~~

~~(3)~~

Maturity is determined based on final settlement period.

AOCI

The following table presents selected information related to ~~gains (losses)~~losses on cash flow hedges included in AOCI in Dominion Energy’s Consolidated Balance Sheet at June 30, ~~2020:~~2021:

AOCI
After-Tax

Amounts Expected to be
Reclassified to Earnings
During the Next 12 Months
After-Tax

Maximum Term
(millions)

Commodities:

Gas

$
(2
)

$
(2
)

18 months
Electricity

8

8

6 months
NGL

—

—

6 months
Interest rate

(640
)

(59
)

378 months
Foreign currency

(10
)

(4
)

72 months
Total

$
(644
)

$
(57
)

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(371	)	$	(43	)	390 months
Total	$	(371	)	$	(43	)

The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., ~~anticipated sales)~~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 ~~market prices,~~ interest ~~rates and foreign currency exchange~~ rates.

In connection with the agreement Dominion Energy entered in July 2020 for the disposition of substantially all of its gas transmission and storage operations, certain cash flow hedges of debt-related items will become probable of not occurring. See Note 3 for further information.

Fair Value Hedges

For derivative instruments that are designated and qualify as a fair value hedge, the gain or loss on the derivative instrument as well as the offsetting loss or gain on the hedged item attributable to the hedged risk are recognized in current earnings and presented in the same line item. There were 0 derivative instruments designated inas fair value hedges during the three and six months ended June 30, ~~2020. Gains~~2021 and ~~losses on derivatives in fair value hedge relationships were immaterial for the three and six months ended June 30, 2019.~~2020.

The following table presents the amounts recorded on the balance sheet related to cumulative basis adjustments for fair value hedges:

	Carrying Amount of the Hedged Asset (Liability)⁽¹⁾						Cumulative Amount of Fair Value Hedging Adjustments Included in the Carrying Amount of the Hedged Assets (Liabilities)⁽²⁾						Carrying Amount of the Hedged Asset (Liability)⁽¹⁾						Cumulative Amount of Fair Value Hedging Adjustments Included in the Carrying Amount of the Hedged Assets (Liabilities)⁽²⁾
	June 30, 2020			December 31, 2019			June 30, 2020			December 31, 2019			June 30, 2021			December 31, 2020			June 30, 2021			December 31, 2020
(millions)
Long-term debt	$	(1,154	)	$	(1,154	)	$	(4	)	$	(4	)	$	(1,153	)	$	(1,153	)	$	(3	)	$	(3	)

(1)	Includes ~~$(1.1)~~$(1.2) billion ~~and $(397) million~~ related to discontinued hedging relationships at both June 30, ~~2020~~2021 and December 31, ~~2019, respectively.~~2020.

(2)	Includes ~~$(4) million and $3~~$(3) million of hedging adjustments on discontinued hedging relationships at both June 30, ~~2020~~2021 and December 31, ~~2019, respectively.~~2020.

Fair Value and Gains and Losses on Derivative Instruments

The following table presents the fair values of Dominion Energy’s derivatives and where they are presented in its Consolidated Balance Sheets:

	Fair Value – Derivatives under Hedge Accounting		Fair Value – Derivatives not under Hedge Accounting		Total Fair Value		Fair Value – Derivatives under Hedge Accounting		Fair Value – Derivatives not under Hedge Accounting		Total Fair Value
(millions)
June 30, 2020
June 30, 2021
ASSETS
Current Assets
Commodity	$	—	$	73	$	73	$	0	$	76	$	76
Interest rate		—		8		8		0		24		24
Total current derivative assets⁽¹⁾		—		81		81		0		100		100
Noncurrent Assets
Commodity		—		109		109		0		72		72
Interest rate		—		26		26		172		272		444
Total noncurrent derivative assets⁽²⁾		—		135		135		172		344		516
Total derivative assets	$	—	$	216	$	216	$	172	$	444	$	616
LIABILITIES
Current Liabilities
Commodity	$	—	$	42	$	42	$	0	$	172	$	172
Interest rate		514		25		539		253		10		263
Foreign currency		5		—		5
Total current derivative liabilities		519		67		586
Total current derivative liabilities⁽³⁾								253		182		435
Noncurrent Liabilities
Commodity		—		8		8		0		73		73
Interest rate		655		78		733		31		35		66
Foreign currency		7		—		7
Total noncurrent derivative liabilities		662		86		748
Total noncurrent derivative liabilities⁽⁴⁾								31		108		139
Total derivative liabilities	$	1,181	$	153	$	1,334	$	284	$	290	$	574
December 31, 2019
December 31, 2020
ASSETS
Current Assets
Commodity	$	30	$	37	$	67	$	0	$	58	$	58
Interest rate		1		—		1		0		9		9
Total current derivative assets⁽¹⁾		31		37		68		0		67		67
Noncurrent Assets
Commodity		1		6		7		0		109		109
Interest rate		10		—		10		66		155		221
Foreign currency		8		—		8
Total noncurrent derivative assets⁽²⁾		19		6		25		66		264		330
Total derivative assets	$	50	$	43	$	93	$	66	$	331	$	397
LIABILITIES
Current Liabilities
Commodity	$	6	$	77	$	83	$	0	$	42	$	42
Interest rate		321		1		322		363		10		373
Foreign currency		3		—		3
Total current derivative liabilities		330		78		408
Total current derivative liabilities⁽³⁾								363		52		415
Noncurrent Liabilities
Commodity		1		47		48		0		13		13
Interest rate		267		17		284		19		39		58
Total noncurrent derivative liabilities		268		64		332
Total noncurrent derivative liabilities⁽⁴⁾								19		52		71
Total derivative liabilities	$	598	$	142	$	740	$	382	$	104	$	486

(1)

Current derivative assets ~~are presented~~include $87 million and $63 million in other current assets in Dominion Energy’s Consolidated Balance Sheets as of June 30, 2021 and December 31, 2020, respectively. The remainder is recorded in current assets held for sale in Dominion Energy’s Consolidated Balance Sheets.

(2)	Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Energy’s Consolidated Balance Sheets.

(3)

Current derivative liabilities include $428 million and $412 million in other current liabilities in Dominion Energy’s Consolidated Balance Sheets as of June 30, 2021 and December 31, 2020, respectively. The remainder is in current liabilities held for sale in Dominion Energy’s Consolidated Balance Sheets.

(4)	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy’s Consolidated Balance Sheets.

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

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 June 30, 2021
Derivative type and location of gains (losses):
Interest rate⁽³⁾										$	(21	)	$	(16	)	$	(219	)
Total										$	(21	)	$	(16	)	$	(219	)
Three Months Ended June 30, 2020
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	9								$	8
Discontinued operations														1
Total commodity										$	—		$	9		$	—
Interest rate:
Interest and related charges														(18	)
Discontinued operations														(4	)
Total interest rate											—			(22	)		14
Foreign currency⁽⁴⁾											6			6			—
Total										$	6		$	(7	)	$	14
Six Months Ended June 30, 2021
Derivative type and location of gains (losses):
Commodity:
Purchased gas					—								$	(1	)
Total commodity	$	—		$	9		$	—		$	—		$	(1	)	$	—
Interest rate⁽³⁾		—			(22	)		14			31			(32	)		189
Foreign currency⁽⁴⁾		6			6			—
Total	$	6		$	(7	)	$	14
Three Months Ended June 30, 2019
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	38
Total commodity	$	35		$	38		$	—
Interest rate⁽³⁾		(142	)		(13	)		(131	)
Foreign currency⁽⁴⁾		2			4			—
Total	$	(105	)	$	29		$	(131	)	$	31		$	(33	)	$	189
Six Months Ended June 30, 2020
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	16								$	14
Purchased gas					(3	)								(3	)
Electric fuel and other energy-related purchases					—
Discontinued operations														2
Total commodity	$	—		$	13		$	—		$	—		$	13		$	—
Interest rate⁽³⁾		(336	)		(49	)		(550	)
Interest rate:
Interest and related charges														(43	)
Discontinued operations														(6	)
Total interest rate											(336	)		(49	)		(550	)
Foreign currency⁽⁴⁾		(17	)		—			—			(17	)		—			—
Total	$	(353	)	$	(36	)	$	(550	)	$	(353	)	$	(36	)	$	(550	)
Six Months Ended June 30, 2019
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	92
Purchased gas					3
Total commodity	$	101		$	95		$	—
Interest rate⁽³⁾		(226	)		(23	)		(215	)
Foreign currency⁽⁴⁾		(9	)		(2	)		—
Total	$	(134	)	$	70		$	(215	)

(1)	Amounts deferred into AOCI have no associated effect in Dominion Energy’s 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 Dominion Energy’s Consolidated Statements of Income.

(3) Amounts recorded in Dominion Energy’s Consolidated Statement of Income are classified in interest and related charges.

(4) Amounts recorded in Dominion Energy’s Consolidated Statement of Income are classified in discontinued operations.

~~(3)~~

~~Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges.~~

~~(4)~~

~~Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in other income (expense).~~

Derivatives not designated as hedging instruments	Amount of Gain (Loss) Recognized in Income on Derivatives⁽¹⁾												Amount of Gain (Loss) Recognized in Income on Derivatives⁽¹⁾
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	(10	)	$	27		$	55		$	30		$	(146	)	$	(5	)	$	(187	)	$	46
Purchased gas		—			(11	)		(14	)		(8	)		7			1			7			(10	)
Electric fuel and other energy-related purchases		(8	)		(3	)		(73	)		(12	)		7			(8	)		(37	)		(73	)
Interest rate⁽²⁾		(25	)		—			(86	)		—
Discontinued operations														0			(6	)		0			5
Interest rate:
Interest and related charges														(157	)		(25	)		162			(78	)
Discontinued operations														0			0			0			(8	)
Total	$	(43	)	$	13		$	(118	)	$	10		$	(289	)	$	(43	)	$	(55	)	$	(118	)

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

~~(2)~~

~~Amounts recorded in Dominion Energy’s Consolidated Statements of Income are classified in interest and related charges.~~

Virginia Power

Balance Sheet Presentation

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

	June 30, 2020								December 31, 2019								June 30, 2021								December 31, 2020
	Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								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		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)
Commodity contracts:
Over-the-counter	$	129	$	5	$	—	$	124	$	19	$	18	$	—	$	1	$	84	$	10	$	0	$	74	$	111	$	6	$	0	$	105
Exchange																		1		1		0		0	1		1			0		0
Interest rate contracts:
Over-the-counter		—		—		—		—		2		—		—		2		172		19		0		153	66		7			0		59
Total derivatives, subject to a master netting or similar arrangement	$	129	$	5	$	—	$	124	$	21	$	18	$	—	$	3	$	257	$	30	$	0	$	227	$	178	$	14	$	0	$	164

(1)	Excludes $4$26 million and $3 million of derivative assets at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, which are not subject to master netting or similar arrangements.

	June 30, 2020								December 31, 2019								June 30, 2021								December 31, 2020
	Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								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		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)
Commodity contracts:
Over-the-counter	$	5	$	5	$	—	$	—	$	59	$	18	$	—	$	41	$	42	$	10	$	9	$	23	$	6	$	6	$	0	$	0
Exchange																		8		1		7		0	1		1			0		0
Interest rate contracts:
Over-the-counter		980		—		—		980		363		—		—		363		283		19		0		264	376		7			0		369
Total derivatives, subject to a master netting or similar arrangement	$	985	$	5	$	—	$	980	$	422	$	18	$	—	$	404	$	333	$	30	$	16	$	287	$	383	$	14	$	0	$	369

(1)	Excludes ~~$19~~$2 million and ~~$44~~$22 million of derivative liabilities at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, which are not subject to master netting or similar arrangements.

Volumes

The following table presents the volume of Virginia Power’s derivative activity at June 30, ~~2020.~~2021. 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 its long and short positions.

	Current		Noncurrent		Current		Noncurrent
Natural Gas (bcf):
Fixed price⁽¹⁾		38		8		29		14
Basis		143		507		143		464
Electricity (MWh):
Fixed price						3,852,994		3,271,323
FTRs		101,087,887		—		98,414,736		0
Interest rate⁽²⁾	$	900,000,000	$	1,150,000,000
Interest rate⁽²⁾ (millions)					$	850	$	1,900

(1)	Includes options.

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

AOCI

The following table presents selected information related to ~~gains (losses)~~losses on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at June 30, ~~2020:~~2021:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(78	)	$	(1	)	378 months	$	(39	)	$	(2	)	390 months
Total	$	(78	)	$	(1	)		$	(39	)	$	(2	)

The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest payments) in earnings, thereby achieving the realization of interest rates 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 Virginia Power’s derivatives and where they are presented in its Consolidated Balance Sheets:

	Fair Value – Derivatives under Hedge Accounting		Fair Value – Derivatives not under Hedge Accounting		Total Fair Value		Fair Value – Derivatives under Hedge Accounting		Fair Value – Derivatives not under Hedge Accounting		Total Fair Value
(millions)
June 30, 2020
ASSETS
Current Assets
Commodity	$	—	$	31	$	31
Total current derivative assets⁽¹⁾		—		31		31
Noncurrent Assets
Commodity		—		102		102
Total noncurrent derivative assets⁽²⁾		—		102		102
Total derivative assets	$	—	$	133	$	133
LIABILITIES
Current Liabilities
Commodity	$	—	$	23	$	23
Interest rate		455		—		455
Total current derivative liabilities		455		23		478
Noncurrent Liabilities
Commodity		—	1			1
Interest rate		525		—		525
Total noncurrent derivatives liabilities⁽³⁾		525		1		526
Total derivative liabilities	$	980	$	24	$	1,004
December 31, 2019
June 30, 2021
ASSETS
Current Assets
Commodity	$	—	$	20	$	20	$	0	$	52	$	52
Total current derivative assets⁽¹⁾		—		20		20		0		52		52
Noncurrent Assets
Commodity		—		2		2		0		59		59
Interest rate		2		—		2		172		0		172
Total noncurrent derivative assets⁽²⁾		2		2		4		172		59		231
Total derivative assets	$	2	$	22	$	24	$	172	$	111	$	283
LIABILITIES
Current Liabilities
Commodity	$	—	$	58	$	58	$	0	$	43	$	43
Interest rate		185		—		185		253		0		253
Total current derivatives liabilities⁽⁴⁾		185		58		243
Total current derivative liabilities								253		43		296
Noncurrent Liabilities
Commodity		—		45		45		0		9		9
Interest rate		178		—		178		30		0		30
Total noncurrent derivatives liabilities⁽³⁾		178		45		223
Total noncurrent derivative liabilities⁽³⁾								30		9		39
Total derivative liabilities	$	363	$	103	$	466	$	283	$	52	$	335
December 31, 2020
ASSETS
Current Assets
Commodity							$	0	$	22	$	22
Total current derivative assets⁽¹⁾								0		22		22
Noncurrent Assets
Commodity								0		93		93
Interest rate								66		0		66
Total noncurrent derivative assets⁽²⁾								66		93		159
Total derivative assets							$	66	$	115	$	181
LIABILITIES
Current Liabilities
Commodity							$	0	$	28	$	28
Interest rate								362		0		362
Total current derivative liabilities								362		28		390
Noncurrent Liabilities
Commodity								0		1		1
Interest rate								14		0		14
Total noncurrent derivative liabilities⁽³⁾								14		1		15
Total derivative liabilities							$	376	$	29	$	405

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

(2)	Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power’s Consolidated Balance Sheets.

(3)	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.

~~(4)~~

~~Current derivative liabilities are presented in other current liabilities in Virginia Power’s Consolidated Balance Sheets.~~

The following tables present the gains and losses on Virginia Power’s derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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 June 30, 2021
Derivative type and location of gains (losses):
Interest rate⁽³⁾										$	(17	)	$	—		$	(221	)
Total										$	(17	)	$	—		$	(221	)
Three Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	2		$	(1	)	$	13		$	2		$	(1	)	$	13
Total	$	2		$	(1	)	$	13		$	2		$	(1	)	$	13
Three Months Ended June 30, 2019
Six Months Ended June 30, 2021
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(15	)	$	(1	)	$	(133	)	$	26		$	(1	)	$	186
Total	$	(15	)	$	(1	)	$	(133	)	$	26		$	(1	)	$	186
Six Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(59	)	$	(1	)	$	(552	)	$	(59	)	$	(1	)	$	(552	)
Total	$	(59	)	$	(1	)	$	(552	)	$	(59	)	$	(1	)	$	(552	)
Six Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(24	)	$	(1	)	$	(218	)
Total	$	(24	)	$	(1	)	$	(218	)

(1)	Amounts deferred into AOCI have no associated effect in Virginia Power’s 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 Virginia Power’s Consolidated Statements of Income.

(3)	Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges.

Derivatives not designated as hedging instruments	Amount of Gain (Loss) Recognized in Income on Derivatives⁽¹⁾												Amount of Gain (Loss) Recognized in Income on Derivatives⁽¹⁾
	Three Months Ended						Six Months Ended						Three Months Ended						Six Months Ended
	June 30,						June 30,						June 30,						June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Derivative type and location of gains (losses):
Commodity⁽²⁾	$	(8	)	$	(3	)	$	(73	)	$	(12	)
Commodity:
Operating revenue													$	(4	)	$	0		$	(6	)	$	0
Electric fuel and other energy-related purchases														7			(8	)		(37	)		(73	)
Total	$	(8	)	$	(3	)	$	(73	)	$	(12	)	$	3		$	(8	)	$	(43	)	$	(73	)

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

~~(2)~~

~~Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.~~

~~Dominion Energy Gas~~

~~Balance Sheet Presentation~~

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

June 30, 2020

December 31, 2019

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross Assets
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Received

Net
Amounts

Gross Assets
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Received

Net
Amounts

(millions)

Foreign currency contracts:

Over-the-counter

$
—

$
—

$
—

$
—

$
8

$
8

$
—

$
—

Total derivatives, subject to a
master netting or similar
arrangement

$
—

$
—

$
—

$
—

$
8

$
8

$
—

$
—

June 30, 2020

December 31, 2019

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross
Liabilities Presented
in the Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Paid

Net
Amounts

Gross
Liabilities Presented
in the Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Paid

Net
Amounts

(millions)

Interest rate contracts:

Over-the-counter

$
192

$
—

$
—

$
192

$
83

$
5

$
—

$
78

Foreign currency contracts:

Over-the-counter

12

—

—

12

3

3

—

—

Total derivatives, subject to a
master netting or similar
arrangement

$
204

$
—

$
—

$
204

$
86

$
8

$
—

$
78

~~Volumes~~

The following table presents the volume of Dominion Energy Gas’ derivative activity at June 30, 2020. 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 its long and short positions.

Current

Noncurrent

Interest rate⁽¹⁾

$
750,000,000

$
550,000,000

Foreign currency⁽¹⁾

€
-

€
250,000,000

~~(1)~~

~~Maturity is determined based on final settlement period.~~

~~AOCI~~

~~The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Energy Gas’ Consolidated Balance Sheet at June 30, 2020:~~

AOCI
After-Tax

Amounts Expected
to be Reclassified to
Earnings During the
Next 12 Months
After-Tax

Maximum Term
(millions)

Interest rate

$
(158
)

$
(11
)

294 months
Foreign currency

(10
)

(4
)

72 months
Total

$
(168
)

$
(15
)

The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest 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 and foreign currency exchange rates.

~~Fair Value and Gains and Losses on Derivative Instruments~~

~~The following tables present the fair values of Dominion Energy Gas’ derivatives and where they are presented in its Consolidated Balance Sheets:~~

Fair Value-
Derivatives
Under Hedge
Accounting

Fair Value-Derivatives
Not Under Hedge
Accounting

Total Fair Value

(millions)

June 30, 2020

LIABILITIES

Current Liabilities

Interest rate

$
58

$
13

$
71

Foreign currency

5

—

5

Total current derivative liabilities⁽²⁾

63

13

76

Noncurrent Liabilities

Interest rate

121

—

121

Foreign currency

7

—

7

Total noncurrent derivative liabilities⁽³⁾

128

—

128

Total derivative liabilities

$
191

$
13

$
204

December 31, 2019

ASSETS

Noncurrent Assets

Foreign currency

$
8

$
—

$
8

Total noncurrent derivative assets⁽¹⁾

8

—

8

Total derivative assets

$
8

$
—

$
8

LIABILITIES

Current Liabilities

Interest rate

$
30

$
—

$
30

Foreign currency

3

—

3

Total current derivative liabilities⁽²⁾

33

—

33

Noncurrent Liabilities

Interest rate

53

—

53

Total noncurrent derivative liabilities⁽³⁾

53

—

53

Total derivative liabilities

$
86

$
—

$
86

~~(1)~~

~~Noncurrent derivatives assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets.~~

~~(2)~~

~~Current derivative liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.~~

~~(3)~~

~~Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.~~

The following table presents the gains and losses on Dominion Energy Gas’ derivatives, as well as where the associated activity is presented in its Consolidated Balance Sheets and Statements of Income:

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

(millions)

Three Months Ended June 30, 2020

Derivative type and location of gains (losses):

Interest rate⁽²⁾

$
(4
)

$
(4
)
Foreign currency⁽³⁾

5

6

Total

$
1

$
2

Three Months Ended June 30, 2019

Derivative type and location of gains (losses):

Commodity:

Net income from discontinued operations

$
—

Total commodity

$
3

$
—

Interest rate⁽²⁾

(36
)

(2
)
Foreign currency⁽³⁾

1

4

Total

$
(32
)

$
2

Six Months Ended June 30, 2020

Derivative type and location of gains (losses):

Interest rate⁽²⁾

(105
)

(6
)
Foreign currency⁽³⁾

(17
)

—

Total

$
(122
)

$
(6
)
Six Months Ended June 30, 2019

Derivative type and location of gains (losses):

Commodity:

Net income from discontinued operations

$
2

Total commodity

$
2

$
2

Interest rate⁽²⁾

(60
)

(1
)
Foreign currency⁽³⁾

(10
)

(2
)
Total

$
(68
)

$
(1
)

~~(1)~~

~~Amounts deferred into AOCI have no associated effect in Dominion Energy Gas’ Consolidated Statements of Income.~~

~~(2)~~

~~Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in interest and related charges.~~

~~(3)~~

~~Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in other income.~~

Derivatives not designated as hedging instruments

Amount of Gain (Loss) Recognized in Income on Derivatives

Three Months Ended

Six Months Ended

June 30,

June 30,

2020

2019

2020

2019

(millions)

Derivative type and location of gains (losses):

Interest rate⁽¹⁾

$
—

$
—

$
(8
)

$
—

Total

$
—

$
—

$
(8
)

$
—

~~(1)~~

~~Amounts recorded in Dominion Energy Gas’ Consolidated Statements of Income are classified in interest and related charges.~~

Note 10. Investments

Dominion Energy

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 ~~$121~~$117 million and ~~$120~~$134 million at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively.

Decommissioning Trust Securities

Dominion Energy holds equity and fixed income securities, insurance contracts and cash equivalents in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Dominion Energy’s decommissioning trust funds are summarized below:

	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)
June 30, 2020
June 30, 2021
Equity securities:⁽¹⁾
U.S.	$	1,701		$	2,221	$	(71	)		$	—		$	3,851		$	1,529		$	3,251	$	(9	)				$	4,771
Fixed income securities:⁽²⁾
Corporate debt instruments		577			48		(1	)			—			624			830			43		(2	)		$	0		871
Government securities		1,119			62		(1	)			—			1,180			1,435			60		(5	)			0		1,490
Common/collective trust funds		146			2		—				—			148			171			5		0				0		176
Insurance contracts		223			—		—				—			223			246			—		—						246
Cash equivalents and other⁽³⁾		(8	)		2		(2	)			—			(8	)		(22	)		5		(16	)			0		(33	)
Total	$	3,758		$	2,335	$	(75	)	⁽⁴⁾	$	—	⁽⁵⁾	$	6,018		$	4,189		$	3,364	$	(32	)	⁽⁴⁾	$	0	$	7,521
December 31, 2019
December 31, 2020
Equity securities:⁽¹⁾
U.S.	$	1,807		$	2,451	$	(20	)		$	—		$	4,238		$	1,756		$	2,948	$	(24	)				$	4,680
Fixed income securities:⁽²⁾
Corporate debt instruments		434			29		—				—			463			572			58		(1	)		$	0		629
Government securities		1,108			39		(2	)			—			1,145			1,119			66		(1	)			0		1,184
Common/collective trust funds		115			4		—				—			119			170			5		0				0		175
Insurance contracts		214			—		—				—			214			237			0		0						237
Cash equivalents and other⁽³⁾		13			—		—				—			13			(8	)		4		(1	)			0		(5	)
Total	$	3,691		$	2,523	$	(22	)	⁽⁴⁾	$	—		$	6,192		$	3,846		$	3,081	$	(27	)	⁽⁴⁾	$	0	$	6,900

(1)	U~~nrealized~~Unrealized gains and losses on equity securities are included in other income 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. ~~Effective January 2020, changes~~Changes in allowance for credit losses are included in other income.

(3)	Includes pending purchases of securities of ~~$35~~$33 million and $1$49 million at June 30, ~~2020~~2021 and December 31, ~~2019, respectively~~.2020, respectively.

(4)	The fair value of securities in an unrealized loss position was ~~$181~~$611 million and ~~$298~~$293 millionat June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively.

~~(5)~~

The allowance for credit losses associated with fixed income securities decreased from March 31, 2020 by $21 million. These recoveries are a result of improvements in credit spreads experienced in the market between March 31, 2020 and June 30, 2020.

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

	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Net gains (losses) recognized during the period	$	610		$	156		$	(288	)	$	570		$	352		$	610		$	631		$	(288	)
Less: Net (gains) losses recognized during the period on securities sold during the period		(5	)		(25	)		9			(44	)		(134	)		(5	)		(312	)		9
Unrealized gains (losses) recognized during the period on securities still held at June 30, 2020 and 2019⁽¹⁾	$	605		$	131		$	(279	)	$	526
Unrealized gains (losses) recognized during the period on securities still held at period end⁽¹⁾													$	218		$	605		$	319		$	(279	)

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

The fair value of Dominion Energy’s fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at June 30, ~~2020~~2021 by contractual maturity is as follows:

	Amount		Amount
(millions)
Due in one year or less	$	212	$	293
Due after one year through five years		486		673
Due after five years through ten years		485		677
Due after ten years		769		894
Total	$	1,952	$	2,537

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

	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019		2021		2020		2021		2020
(millions)
Proceeds from sales	$	1,058	$	376	$	1,660	$	882	$	945	$	1,058	$	2,710	$	1,660
Realized gains⁽¹⁾		74		56		140		99		148		74		380		140
Realized losses⁽¹⁾		61		27		130		50		15		61		74		130

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

Virginia Power

Virginia Power holds equity and fixed income securities and cash equivalents in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Virginia Power’s decommissioning trust funds are summarized below:

	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)
June 30, 2020
June 30, 2021
Equity securities:⁽¹⁾
U.S.	$	901		$	1,028	$	(46	)		$	—		$	1,883		$	817		$	1,497	$	(8	)				$	2,306
Fixed income securities:⁽²⁾
Corporate debt instruments		328			26		—				—			354			463			24		(1	)		$	0		486
Government securities		467			23		(1	)			—			489			645			24		(1	)			0		668
Common/collective trust funds		57			—		—				—			57			55			0		0				0		55
Cash equivalents and other⁽³⁾		(1	)		—		—				—			(1	)		(4	)		—		—				0		(4	)
Total	$	1,752		$	1,077	$	(47	)	⁽⁴⁾	$	—	⁽⁵⁾	$	2,782		$	1,976		$	1,545	$	(10	)	⁽⁴⁾	$	0	$	3,511
December 31, 2019
December 31, 2020
Equity securities:⁽¹⁾
U.S.	$	894		$	1,144	$	(11	)		$	—		$	2,027		$	929		$	1,371	$	(21	)				$	2,279
Fixed income securities:⁽²⁾
Corporate debt instruments		241			15		—				—			256			315			33		0			$	0		348
Government securities		534			14		(2	)			—			546			484			25		—				0		509
Common/collective trust funds		51			—		—				—			51			58			0		0				0		58
Cash equivalents and other(3)		1			—		—				—			1			3			—		—				0		3
Total	$	1,721		$	1,173	$	(13	)	⁽⁴⁾	$	—		$	2,881		$	1,789		$	1,429	$	(21	)	⁽⁴⁾	$	0	$	3,197

(1)	Unrealized gains and losses on equity securities are included in other income 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. ~~Effective January 2020, changes~~Changes in allowance for credit losses are included in other income.

(3)	Includes pending purchasesof securities of $1$4 million and $10 million at June 30, ~~2020.~~2021 and December 31, 2020, respectively.

(4)	The fair value of securities in an unrealized loss position was ~~$74~~$228 million and ~~$185~~$142 million at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively.

~~(5)~~

The allowance for credit losses associated with fixed income securities decreased from March 31, 2020 by $12 million. These recoveries are a result of improvements in credit spreads experienced in the market between March 31, 2020 and June 30, 2020.

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

	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Net gains (losses) recognized during the period	$	269		$	70		$	(154	)	$	256		$	170		$	269		$	313		$	(154	)
Less: Net (gains) losses recognized during the period on securities sold during the period		(3	)		(7	)		3			(8	)		(85	)		(3	)		(173	)		3
Unrealized gains (losses) recognized during the period on securities still held at June 30, 2020 and 2019⁽¹⁾	$	266		$	63		$	(151	)	$	248
Unrealized gains (losses) recognized during the period on securities still held at period end⁽¹⁾													$	85		$	266		$	140		$	(151	)

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

The fair value of Virginia Power’s fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at June 30, ~~2020~~2021 by contractual maturity is as follows:

	Amount		Amount
(millions)
Due in one year or less	$	79	$	82
Due after one year through five years		227		340
Due after five years through ten years		273		401
Due after ten years		321		386
Total	$	900	$	1,209

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

	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019		2021		2020		2021		2020
(millions)
Proceeds from sales	$	236	$	194	$	530	$	447	$	460	$	236	$	1,249	$	530
Realized gains⁽¹⁾		24		15		55		25		90		24		196		55
Realized losses⁽¹⁾		17		3		48		12		3		17		26		48

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

Equity Method Investments

Dominion Energy

~~Dominion Energy’s~~ recorded equity earnings ~~(losses)~~ on its investments ~~totaled $(2.2) billion~~of $145 million and ~~$80~~$5 million for the six months ended June 30, 2021 and 2020, respectively, in earnings from equity method investees in its Consolidated Statements of Income. In addition, Dominion Energy recorded equity losses of $22 millionand ~~2019, respectively.~~$2.3 billion for the six months ended June 30, 2021 and 2020, respectively, in discontinued operations related to its investment in Atlantic Coast Pipeline. Dominion Energy received distributions of ~~$46~~$166 million and ~~$57~~$46 million for the six months ended June 30, 2021 and 2020, respectively. Dominion Energy made contributions of $1.0 billion and ~~2019,~~$37 million for the six months ended June 30, 2021 and 2020 respectively. At June 30, ~~2020~~2021, Dominion Energy had $20 million of contributions payable to equity method affiliates included within other current liabilities in its Consolidated Balance Sheet. At June 30, 2021 and December 31, ~~2019,~~2020, the net difference between the carrying amount of Dominion Energy’s investments and its share of underlying equity in net assets was ~~$96~~$234 million and ~~$110~~$213 million, respectively. At June 30, ~~2020,~~2021, these differences are comprised of ~~$175~~$27 million of equity method goodwill that is not being amortized, ~~and~~ a net $79 million basis difference primarily attributable to Dominion Energy’s investments in Fowler Ridge and an unfunded commitment made to Align RNG. At December 31, 2019, these differences are comprised of $159 million of equity method goodwill that is not being amortized and a net $49$224 million basis difference from Dominion Energy’s ~~investments~~investment in ~~Fowler Ridge,~~Cove Point, which is being amortized over the useful lives of the underlying assets, and a net $(17) million basis difference primarily attributable to an unfunded commitment made to Align RNG. At December 31, 2020, these differences are comprised of $27 million of equity method goodwill that is not being amortized, a $227 million basis difference from Dominion Energy’s investment in ~~Atlantic Coast Pipeline,~~Cove Point, which is being amortized over the ~~term~~useful lives of ~~its credit facility,~~the underlying assets, and a net $(41) million basis difference primarily attributable to an unfunded commitment made to Align RNG.

~~Atlantic Coast Pipeline~~Cove Point

In ~~September 2014,~~November 2020, in conjunction with the GT&S Transaction, Dominion Energy ~~along with Duke Energy~~sold 100% of its general partner interest and ~~Southern, announced~~25% of the formation of Atlantic Coast Pipeline for the purpose of constructing an approximately 600-mile natural gas pipeline running from West Virginia through Virginia to North Carolina. Subsidiaries and affiliates oftotal limited partner interest in Cove Point. Dominion Energy ~~Duke Energy and Southern had planned to be customers of the pipeline under 20-year contracts.~~

In March 2020, Dominion Energy completed the acquisition from Southern of its 5% membership interest in Atlantic Coast Pipeline and its 100% ownership interest in Pivotal LNG, Inc., for $184 million in aggregate, subject to certain purchase price adjustments. Pivotal LNG, Inc. includesretained a 50% noncontrolling limited partnership interest in ~~JAX LNG. Following completion of the acquisition, Dominion Energy owns a 53% noncontrolling membership interest in Atlantic Coast Pipeline with Duke Energy owning the remaining interest.~~ Cove

~~Atlantic Coast Pipeline continues to be reflected~~50

Point which is accounted for as an equity method investment, as discussed in Note 9 to the ~~power to direct~~Consolidated Financial Statements in the activities most significant to Atlantic Coast Pipeline is shared with Duke Energy. As a result, Dominion Energy has the ability to exercise significant influence, but not control, over the investee.

The Atlantic Coast Pipeline Project had been the subject of challenges in federal courts including, among others, challenges of the Atlantic Coast Pipeline Project’s biological opinion and incidental take statement, permits providing right of way crossings of certain federal lands, the Army Corps of Engineers 404 permit, the air permit for a compressor station at Buckingham, Virginia, and the FERC order approving the CPCN. Each of these challenges alleged non-complianceCompanies’ Annual Report on the part of federal and state permitting authorities and adverse ecological consequences if the Atlantic Coast Pipeline Project was permitted to proceed. Since December 2018, notable developments in these challenges included a stay in December 2018 issued by the U.S. Court of AppealsForm 10-K for the ~~Fourth Circuit~~year ended December 31, 2020.

Income before income taxes recorded by Cove Point was $136 million and the same court’s July 2019 vacatur of the biological opinion and incidental take statement (which stay and subsequent vacatur halted most project construction activity), the U.S. Court of Appeals for the Fourth Circuit decisions vacating the permits to cross certain federal forests and the air permit for a compressor station at Buckingham, Virginia, the U.S. Court of Appeals for the Fourth Circuit’s remand to the Army Corps of Engineers of Atlantic Coast Pipeline’s Huntington District 404 verification and the U.S. Court of Appeals for the Fourth Circuit’s remand to the National Park Service of Atlantic Coast Pipeline’s Blue Ridge Parkway right-of-way. In June 2019, the Solicitor General of the U.S. and Atlantic Coast Pipeline filed petitions requesting that the Supreme Court of the U.S. hear the case regarding the Appalachian Trail crossing and in June 2020, the Supreme Court of the U.S. ruled in favor of the Atlantic Coast Pipeline, reversing the lower court’s decision and remanding the case back to the U.S. Court of Appeals for the Fourth Circuit.

The project also faced new and serious challenges from uncertainty related to NWP 12, specifically, from the decision of the U.S. District Court for the District of Montana in April 2020 vacating an NWP 12 issued by the Army Corps of Engineers, including among other things gas pipelines, followed by a U.S. Court of Appeals for the Ninth Circuit ruling in May 2020 denying a stay of that decision. In July 2020, the Supreme Court of the U.S. issued an order allowing other new oil and gas pipeline projects to use the NWP 12 process pending appeal to the U.S. Court of Appeals for the Ninth Circuit; however, that did not decrease the uncertainty associated with an eventual ruling. The Montana district court decision was viewed as likely to prompt similar challenges in other federal circuit courts related to permits issued under NWP 12, including for the Atlantic Coast Pipeline Project.

In July 2020, as a result of the continued permitting delays, growing legal uncertainties and the need to incur significant capital expenditures to maintain project timing before such uncertainties could be resolved, Dominion Energy and Duke Energy announced the cancellation of the Atlantic Coast Pipeline Project.

As a result of the determination of the probable abandonment of the Atlantic Coast Pipeline Project in June 2020, Atlantic Coast Pipeline has provided to Dominion Energy that it recorded net losses of $4.4 billion and $4.3 billion$131 million for the three months ended June 30, 2021 and 2020, respectively, and $274 million and $264 million for the six months ended June 30, 2021 and 2020, ~~respectively, compared~~respectively. For the periods prior to ~~net income~~closing of ~~$61~~the GT&S Transaction, earnings attributable to Dominion Energy are presented in discontinued operations and subsequent to the closing, earnings attributable to Dominion Energy are presented within earnings from equity method investees in its Consolidated Statements of Income.

Dominion Energy recorded distributions from Cove Point of $77 million and ~~$114~~$150 million for the three and six months ended June 30, ~~2019, respectively, and that it did not record revenue for any period. As a result, Dominion Energy has recorded within earnings~~

~~(loss) from equity method investees a loss of $2.3 billion for both the three and six months ended June 30, 2020 compared~~2021, respectively. NaN contributions were made to ~~income of $29 million and $53 million~~Cove Point for the three and six months ended June 30, ~~2019, respectively.~~ 2021.

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 Company’s Annual Report on Form 10-K for the year ended December 31, 2020.

At June 30, 2021 and December 31, 2020, Dominion Energy has recorded a liability of ~~$1.0~~$115 million and $1.1 billion, ~~within other current liabilities~~respectively, in its Consolidated Balance ~~Sheet,~~Sheets as a result of its share of equity losses exceeding its investment which reflects Dominion Energy’s obligations on behalf of Atlantic Coast Pipeline related to its credit facility, through February 2021, and AROs.

In ~~October 2017, Dominion Energy entered into a guarantee agreement to support a portion of~~February 2021, Atlantic Coast ~~Pipeline’s obligation under a $3.4 billion~~Pipeline repaid the outstanding borrowed amounts and terminated its revolving credit ~~facility with a stated maturity date of~~ ~~October 2021~~.facility. As of ~~June 30,~~December 31, 2020, Atlantic Coast Pipeline had borrowed $1.8 billion against the revolving credit facility. ~~In July 2020, the capacity~~Concurrently, Dominion Energy’s related guarantee agreement to support its portion of ~~the revolving credit facility~~Atlantic Coast Pipeline’s borrowings was ~~reduced from $3.4 billion to $1.9 billion.~~also terminated. Dominion Energy’s Consolidated Balance Sheets ~~include~~included a liability of ~~$14~~$6 million associated with this guarantee agreement at December 31, 2019. The $1.0 billion liability at June 30, 2020 discussed above includes a $48 million adjustment related to this guarantee agreement that is reflected within equity as a cumulative effect of a change in accounting principle upon adoption of the new credit loss standard in January 2020.

Dominion Energy recorded contributions of $13 ~~million and $33~~ million during the three months ended June 30, 2020, and ~~2019, respectively,~~$965 million and $29 ~~million and $128~~ million during the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively, to Atlantic Coast Pipeline. AtDominion Energy recorded 0 contributions during the three months ended June 30, ~~2020 and December 31, 2019, Dominion Energy had $5 million and $7 million, respectively, of contributions payable~~2021 to Atlantic Coast ~~Pipeline included within other current liabilities in the Consolidated Balance Sheets.~~Pipeline.

Dominion Energy expects to 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. ~~In connection with~~

DETI provided services to Atlantic Coast Pipeline which totaled $17 million and $37 million for the ~~sale~~three and six months ended June 30, 2020, respectively, included in discontinued operations in Dominion Energy’s Consolidated Statements of Income.

Wrangler

A description of Dominion Energy’s ~~gas transmission and storage operations to BHE discussed in Note 3, Dominion Energy expects to reflect the results of its equity method~~ investment in ~~Atlantic Coast Pipeline as discontinued operations effective in the third quarter of 2020.~~

~~Blue Racer~~

In the first quarter of 2019, Dominion Energy received $151 million of additional consideration, including applicable interest, in connection with the sale of Dominion Energy’s 50% limited partnership interest in Blue Racer in December 2018, as discussedWrangler is included in Note 9 to the Consolidated Financial Statements in the ~~Companies’~~Company’s Annual Report on Form 10-K for the year ended December 31, ~~2019.~~

~~Fowler Ridge~~

In July 2020, Dominion Energy entered into an agreement to sell its 50% noncontrolling partnership interest in Fowler Ridge to BP and to terminate a long-term power, capacity and renewable energy credit contract for a net payment by Dominion Energy of $150 million. The transaction is expected to close in the third quarter of 2020, subject to approval by FERC. Dominion Energy expects to record a loss of approximately $220 million ($170 million after-tax), consisting of a loss on the contract termination partially offset by a gain on the sale of the partnership interest.

~~Dominion Energy Gas~~

~~Dominion~~ Energy Gas’ equity earnings totaled $23 million and $22 million for the six months ended June 30, 2020 and 2019, respectively. Dominion Energy Gas received distributions of $25 million and $30 million for the six months ended June 30, 2020 and 2019, respectively.2020. At June 30, ~~2020~~2021 and December 31, ~~2019, the carrying amount of Dominion Energy Gas’ investment of $310~~2020, $60 million and ~~$312~~$63 million ~~respectively, exceeded its share~~ of ~~underlying equity in net~~ assets ~~by $146 million. The difference reflects equity method goodwill~~ and ~~is not being amortized.~~

~~Atlantic Coast Pipeline~~

~~DETI provides services to Atlantic Coast Pipeline which totaled~~ $17 million and ~~$26~~$15 million of liabilities, respectively, associated with the remaining nonregulated retail energy marketing operations expected to be contributed to Wrangler by December 2021 were classified as held for ~~the three months ended June 30, 2020~~sale and ~~2019, respectively, and $37 million and $57 million for the six months ended June 30, 2020 and 2019, respectively,~~were included in ~~operating revenue in~~current assets held for sale and current liabilities held for sale on Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income. Amounts receivable related to these services were $7 million at both June 30, 2020 and December 31, 2019, respectively, composed entirely of accrued unbilled revenue, included in other receivables in Dominion Energy and Dominion Energy Gas’Energy’s Consolidated Balance Sheets. The related disposal group is primarily comprised of customer receivables, goodwill, inventories and accounts payable.

Note 11. Property, Plant and Equipment

Acquisitions of Nonregulated Solar Projects

Other than the items discussed below, there have been no updates to acquisitions of solar projects by ~~Dominion Energy or Virginia Power~~the Companies from those discussed in Note 10 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020.

The following table presents acquisitions by Virginia Power of non-jurisdictional solar projects. Virginia Power has claimed or expects to claim federal investment tax credits on the projects.

Date Agreement Entered

Date Agreement Closed

Project Location

Project Name

Project Cost (millions)⁽¹⁾

Date of Commercial Operations

MW Capacity

May 2020

May 2020

Virginia

Pumpkinseed

$
130

Expected 2022

60

Project Name

Date Agreement Entered

Date Agreement

Closed

Project

Location

Project Cost

(millions)⁽¹⁾

Date of

Commercial

Operations

MW Capacity

Bookers Mill

February 2021

June 2021

Virginia

200

Expected 2023

127

Belcher

June 2019

August 2019

Virginia

164

June 2021

(1)	Includes acquisition cost.

The following table presents acquisitions by Dominion Energy of solar projects. Dominion Energy has claimed or expects to claim federal investment tax credits on the projects.

Date Agreement Entered

Date Agreement Closed

Project Location

Project Name

Project Cost (millions)⁽¹⁾

Date of Commercial Operations

MW Capacity

August 2019

August 2019

Virginia

Myrtle

$
32

June 2020

15

May 2020

May 2020

South Carolina

Blackville

15

Expected 2020

7

May 2020

May 2020

South Carolina

Denmark

15

Expected 2020

6

May 2020

Expected August 2020

South Carolina

Yemassee

20

Expected 2020

10

May 2020

Expected August 2020

South Carolina

Trask

25

Expected 2020

12

June 2020

June 2020

Ohio

Hardin I

250

Expected 2020

150

July 2020

July 2020

Virginia

Madison

125

Expected 2021

62

Project Name

Date Agreement Entered

Date Agreement

Closed

Project

Location

Project Cost

(millions)⁽¹⁾

Date of

Commercial

Operations

MW Capacity

Trask

May 2020

October 2020

South Carolina

March 2021

Hardin II

August 2020

Expected 2021

Ohio

305

Expected 2022

150

(1)	Includes acquisition cost.

In addition to the facilities discussed above, Dominion Energy has also entered into various agreements to install solar facilities, primarily at schools in Virginia, with in-service dates ~~in 2020 or 2021. Through July 2020,~~through 2022. As of June 30, 2021, Dominion Energy anticipates a total projected cost of approximately ~~$35~~$65 million under these agreements with an associated aggregate generation capacity of 1831 MW. Dominion Energy has claimed or expects to claim federal investment tax credits on the projects.

Non-Wholly-Owned Nonregulated Solar Facilities

~~Acquisition of Gathering and Processing Assets~~Sale to Terra Nova Renewable Partners

In ~~March 2020, Wexpro closed on~~August 2021, Dominion Energy entered into an agreement with ~~a natural gas gathering systems operator~~ Terra Nova Renewable Partnersto ~~purchase existing natural gas gathering systems including pipelines, compressors and dehydration equipment~~sell SBL Holdco, which holds Dominion Energy’s remaining 67% controlling interest in certain nonregulated solar projects for ~~total~~ consideration of ~~$38 million. These facilities gather natural gas~~approximately $450 million, subject to customary closing adjustments, with the amount of cash reduced by the amount of SBL Holdco’s debt outstanding at closing. The transaction is expected to close in ~~Colorado, Utah~~the fourth quarter of 2021, contingent on clearance or approval under the Hart-Scott-Rodino Act and ~~Wyoming.~~by FERC as well as other customary closing and regulatory conditions.

Dominion Energy will reclassify the assets and liabilities to be disposed of as held for sale in the third quarter of 2021. Dominion Energy expects to record a gain of approximately $25 million ($27 million after-tax) upon closing.

Note 12. Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2020		December 31, 2019		June 30, 2021		December 31, 2020
(millions)
Dominion Energy
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	—	$	48	$	165	$	—
Deferred project costs and DSM programs for gas utilities⁽²⁾		49		21		52		35
Unrecovered gas costs⁽³⁾		42		102		86		78
Deferred rate adjustment clause costs for Virginia electric utility⁽⁴⁾⁽⁵⁾		58		109
Deferred rider costs for Virginia electric utility⁽⁴⁾						87		98
Deferred nuclear refueling outage costs⁽⁶⁾⁽⁵⁾		60		68		86		53
NND Project costs⁽⁷⁾		138		138
NND Project costs⁽⁶⁾						138		138
PJM transmission rates⁽⁸⁾⁽⁷⁾		21		121		24		71
Other		248		272		235		226
Regulatory assets-current		616		879		873		699
Pension and other postretirement benefit costs⁽⁹⁾⁽⁸⁾		1,392		1,431		1,292		1,363
Deferred rate adjustment clause costs for Virginia electric utility^{(4)(5)(10)(11)}		409		235
PJM transmission rates⁽⁸⁾		154		85
Deferred rider costs for Virginia electric utility⁽⁴⁾						409		311
Deferred project costs for gas utilities⁽²⁾		557		521		642		632
Interest rate hedges⁽¹²⁾		1,302		741
AROs and related funding⁽¹³⁾		312		311
Cost of reacquired debt⁽¹⁴⁾		252		262
NND Project costs⁽⁷⁾		2,434		2,503
Ash pond and landfill closure costs⁽¹⁵⁾		2,139		1,016
Interest rate hedges⁽⁹⁾						848		1,042
AROs and related funding⁽¹⁰⁾						336		331
Cost of reacquired debt⁽¹¹⁾						12		245
NND Project costs⁽⁶⁾						2,295		2,364
Ash pond and landfill closure costs⁽¹²⁾						2,339		2,301
Other		487		582		590		544
Regulatory assets-noncurrent		9,438		7,687		8,763		9,133
Total regulatory assets	$	10,054	$	8,566	$	9,636	$	9,832
Regulatory liabilities:
Deferred cost of fuel used in electric generation⁽¹⁾	$	111	$	—	$	39	$	58
Provision for future cost of removal and AROs⁽¹⁶⁾		142		142
Reserve for refunds and rate credits to electric utility customers⁽¹⁷⁾		134		143
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁸⁾		35		4
Income taxes refundable through future rates⁽¹⁹⁾		140		77
Monetization of guarantee settlement⁽²⁰⁾		67		67
Provision for future cost of removal and AROs⁽¹³⁾						183		183
Reserve for refunds to electric utility customers⁽¹⁴⁾						123		128
Reserve for future credits to Virginia electric customers⁽¹⁵⁾						—		120
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁶⁾						—		12
Income taxes refundable through future rates⁽¹⁷⁾						135		124
Monetization of guarantee settlement⁽¹⁸⁾						67		67
Other		120		64		84		117
Regulatory liabilities-current		749		497		631		809
Income taxes refundable through future rates⁽¹⁹⁾		4,988		5,088
Provision for future cost of removal and AROs⁽¹⁶⁾		2,253		2,302
Nuclear decommissioning trust⁽²¹⁾		1,372		1,471
Monetization of guarantee settlement⁽²⁰⁾		936		970
Reserve for refunds and rate credits to electric utility customers⁽¹⁷⁾		588		656
Overrecovered other postretirement benefit costs⁽²²⁾		212		189
Income taxes refundable through future rates⁽¹⁷⁾						4,299		4,376
Provision for future cost of removal and AROs⁽¹³⁾						2,223		2,150
Nuclear decommissioning trust⁽¹⁹⁾						1,954		1,719
Monetization of guarantee settlement⁽¹⁸⁾						869		903
Reserve for refunds to electric utility customers⁽¹⁴⁾						475		540
Overrecovered other postretirement benefit costs⁽²⁰⁾						89		111
Other		331		325		383		388
Regulatory liabilities-noncurrent		10,680		11,001		10,292		10,187
Total regulatory liabilities	$	11,429	$	11,498	$	10,923	$	10,996

(1)	Reflects deferred fuel expenses for the Virginia, North Carolina and South Carolina jurisdictions of Dominion Energy’s electric generation operations.

(2)	Primarily reflects amounts expected to be collected from or owed to gas customers in Dominion Energy’s service territories associated with current and prospective rider projects, including CEP, PIR and pipeline integrity management. See Note 13 for more information.

(3)	Reflects unrecovered ~~or overrecovered~~ gas costs at regulated gas operations, which are recovered ~~or refunded~~ through filings with the applicable regulatory authority.

(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, net of income taxes refundable from the 2017 Tax Reform Act for Virginia Power.~~projects. See Note 13 for more information.

(5)

As a result of actions from the Virginia Commission in the first quarter of 2019 regarding the ratemaking treatment of excess deferred taxes from the adoption of the 2017 Tax Reform Act for all existing rate adjustment clauses, Virginia Power recorded a $29 million ($22 million after-tax) charge in operating revenue in the Consolidated Statements of Income for amounts which are probable of being returned to customers.

~~(6)~~

Legislation enacted in Virginia in April 2014 requires Virginia Power to defer operation and maintenance costs incurred in connection with the refueling of any nuclear-powered generating plant. These deferred costs will be amortized over the refueling cycle, not to exceed 18 months.

~~(7)~~(6)

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. See Note 3 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019~~2020 for more information.

~~(8)~~(7)

Reflects current portion of amounts to be recovered through retail rates in Virginia for payments Virginia Power ~~will~~expects to make to PJM ~~over a~~ ~~ten-year~~ ~~period ending 2028~~through 2026 under the terms of a FERC settlement agreement in May 2018 resolving a PJM cost allocation matter.

~~(9)~~(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.

~~(10)~~

During the first quarter of 2019, Virginia Power recorded a charge of $17 million ($13 million after-tax) in impairment of assets and other charges to write-off the balance of a regulatory asset for which it is no longer seeking recovery.

~~(11)~~

During the second quarter of 2020, Virginia Power recorded a charge of $16 million ($15 million after-tax) in impairment of assets and other charges to write off the balance of a regulatory asset for which it is no longer seeking recovery.

~~(12)~~(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 27 years as of June 30, ~~2020.~~2021.

~~(13)~~(10)

Represents 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.

~~(14)~~Costs of the reacquisition of debt are deferred and amortized as interest expense over the would-be remaining life of the reacquired debt. The reacquired debt costs had a weighted-average life of approximately 26 years as of June 30, 2020.

~~(15)~~(11)

During the second quarter of 2021, DESC recorded a charge of $237 million ($178 million after-tax) in impairment of assets and other charges to write-off the balance of a regulatory asset that is no longer probable of recovery under the settlement agreement approved in DESC’s retail electric base rate case. See Note 13 for more information.

(12)

Primarily reflects legislation enacted in Virginia in ~~March~~ 2019, which requires any CCR ~~unit~~asset located at certain Virginia Power stations to be closed by removing the ~~CCRs~~CCR to an approved landfill or through ~~recycling for~~ beneficial reuse. ~~Subject to approval by the Virginia Commission, amounts~~These deferred costs are expected to be collected over a period between 15 and 18 years commencing ~~no earlier than 2021.~~December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs once expenditures have been made. See Note ~~23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019~~13 for additional information.~~As a result of the March 2020 planned early retirement of certain facilities, amounts recoverable through riders were reclassified from property, plant and equipment.~~

~~(16)~~(13)

Rates charged to customers by Dominion Energy’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.

~~(17)~~(14)

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. See Notes 3 and 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019~~2020 for more information.

~~(18)~~(15)

Represents a reserve related to the use of a CCRO in accordance with the GTSA associated with the 2021 Triennial Review. See Note 13 for additional information.

(16)

Balance refundable to customers related to the decrease in revenue requirements for recovery of income taxes at the Companies’ regulated electric generation and electric and natural gas distribution operations. See Notes 3 and 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019~~2020 for more information.

~~(19)~~(17)

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.

~~(20)~~(18)

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. See Note 3 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019~~2020 for more information.

~~(21)~~(19)

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

~~(22)~~(20)

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

	June 30, 2021		December 31, 2020
(millions)
Virginia Power
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	165	$	—
Deferred rider costs⁽²⁾		87		98
Deferred nuclear refueling outage costs⁽³⁾		86		53
PJM transmission rates⁽⁴⁾		24		71
Other		100		73
Regulatory assets-current		462		295
Deferred rider costs⁽²⁾		409		311
Interest rate hedges⁽⁵⁾		548		733
Ash pond and landfill closure costs⁽⁶⁾		2,338		2,301
Other		159		164
Regulatory assets-noncurrent		3,454		3,509
Total regulatory assets	$	3,916	$	3,804
Regulatory liabilities:
Deferred cost of fuel used in electric generation⁽¹⁾	$	2	$	58
Provision for future cost of removal⁽⁷⁾		152		152
Reserve for future credits to Virginia electric customers⁽⁸⁾		—		120
Income taxes refundable through future rates⁽⁹⁾		54		54
Other		46		41
Regulatory liabilities-current		254		425
Income taxes refundable through future rates⁽⁹⁾		2,378		2,404
Nuclear decommissioning trust⁽¹⁰⁾		1,954		1,719
Provision for future cost of removal⁽⁷⁾		1,028		980
Deferred cost of fuel used in electric generation⁽¹⁾		—		54
Other		192		181
Regulatory liabilities-noncurrent		5,552		5,338
Total regulatory liabilities	$	5,806	$	5,763

June 30, 2020

December 31, 2019

(millions)

Virginia Power

Regulatory assets:

Deferred cost of fuel used in electric generation⁽¹⁾

$
—

$
48

Deferred rate adjustment clause costs⁽²⁾⁽³⁾

58

109

Deferred nuclear refueling outage costs⁽⁴⁾

60

68

PJM transmission rates⁽⁵⁾

21

121

Other

58

87

Regulatory assets-current

197

433

Deferred rate adjustment clause costs^(2)(3)(6)(7)

409

235

PJM transmission rates⁽⁵⁾

154

85

Interest rate hedges⁽⁸⁾

956

404

Ash pond and landfill closure costs⁽⁹⁾

2,139

1,016

Other

122

123

Regulatory assets-noncurrent

3,780

1,863

Total regulatory assets

$
3,977

$
2,296

Regulatory liabilities:

Deferred cost of fuel used in electric generation⁽¹⁾

$
111

$
—

Provision for future cost of removal⁽¹⁰⁾

103

103

Income taxes refundable through future rates⁽¹¹⁾

54

54

Other

28

10

Regulatory liabilities-current

296

167

Income taxes refundable through future rates⁽¹¹⁾

2,425

2,438

Nuclear decommissioning trust⁽¹²⁾

1,372

1,471

Provision for future cost of removal⁽¹⁰⁾

993

1,054

Deferred cost of fuel used in electric generation⁽¹⁾

3

30

Other

161

81

Regulatory liabilities-noncurrent

4,954

5,074

Total regulatory liabilities

$
5,250

$
5,241

~~(1)~~

(1) Reflects deferred fuel expenses for the Virginia and North Carolina jurisdictions of Virginia Power’s generation operations.

(2)	Reflects deferrals under Virginia Power’s electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider ~~projects, net of income taxes refundable from the 2017 Tax Reform Act for Virginia Power.~~projects. See Note 13 for more information.

(3)

~~(4)~~

~~(5)~~(4)

~~(6)~~

~~(7)~~

~~(8)~~(5)

~~(9)~~(6)

Primarily reflects legislation enacted in Virginia in ~~March~~ 2019, which requires any CCR ~~unit~~asset located at certain Virginia Power stations to be closed by removing the CCR to an approved landfill or through ~~recycling for~~ beneficial reuse. ~~Subject to approval by the Virginia Commission, amounts~~These deferred costs are expected to be collected over a period between 15 and 18 years commencing ~~no earlier than 2021.~~December 2021 through Rider CCR. Virginia Power is entitled to collect carrying costs once expenditures have been made. See Note ~~23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019~~13 for additional information. ~~As a result of the March 2020 planned early retirement of certain facilities, amounts recoverable through riders were reclassified from property, plant and equipment.~~

~~(10)~~(7)

Rates charged to customers by 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.

~~(11)~~(8)

~~Amounts recorded~~Represents a reserve related to ~~pass~~ the ~~effect~~use of ~~reduced income taxes from~~a CCRO in accordance with the ~~2017 Tax Reform Act to customers in future periods, which will reverse at~~GTSA associated with 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.

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

June 30, 2020

December 31, 2019

(millions)

Dominion Energy Gas

Regulatory assets:

Unrecovered gas costs⁽¹⁾

$
2

$
2

Other

7

6

Regulatory assets-current⁽²⁾

9

8

Interest rate hedges⁽³⁾

32

32

Other

5

8

Regulatory assets-noncurrent⁽⁴⁾

37

40

Total regulatory assets

$
46

$
48

Regulatory liabilities:

Provision for future cost of removal and AROs⁽⁵⁾

$
18

$
18

Overrecovered gas costs⁽¹⁾

6

8

Other

13

15

Regulatory liabilities-current⁽⁶⁾

37

41

Income taxes refundable through future rates⁽⁷⁾

566

560

Provision for future cost of removal and AROs⁽⁵⁾

93

95

Overrecovered other postretirement benefit costs⁽⁸⁾

151

133

Other

10

12

Regulatory liabilities-noncurrent⁽⁹⁾

820

800

Total regulatory liabilities

$
857

$
841

~~(1)~~

~~Reflects unrecovered or overrecovered gas costs at regulated gas operations, which are recovered or refunded through filings with FERC.~~2021 Triennial Review. See Note 13 for additional information.

~~(2)~~

~~Current regulatory assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets.~~

~~(3)~~

~~(4)~~

~~Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Energy Gas’ Consolidated Balance Sheets.~~

~~(5)~~

Rates charged to customers by Dominion Energy Gas' 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.

~~(6)~~

~~Current regulatory liabilities are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.~~

~~(7)~~(9)

Amounts recorded to pass the effect of reduced income taxes from the 2017 Tax Reform Act to customers in future periods, which will 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.

~~(8)~~(10)

~~Reflects~~Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the ~~collection~~future decommissioning of ~~postretirement benefit costs allowed in rates~~Virginia Power’s utility nuclear generation stations, in excess of ~~expense incurred.~~

the related AROs.~~(9)~~

~~Noncurrent regulatory liabilities are presented in other deferred credits and other liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.~~

At June 30, ~~2020,~~2021, Dominion Energy and Virginia Power ~~and Dominion Energy Gas’~~ regulatory assets include ~~$4.8 billion, $3.4~~$4.2 billion and ~~$44 million,~~$3.0 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.

Note 13. Regulatory Matters

Regulatory Matters Involving Potential Loss Contingencies

As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For regulatory matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that the Companies are able to estimate a range of possible loss. For regulatory matters that the Companies are able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent the Companies’ maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below,

management does not anticipate that the outcome from such matters would have a material effect on the Companies’ financial position, liquidity or results of operations.

~~FERC – Gas~~

~~DETI~~

In July 2017, FERC audit staff communicated to DETI that it had substantially completed an audit of DETI’s compliance with the accounting and reporting requirements of FERC’s Uniform System of Accounts and provided a description of matters and preliminary recommendations. In November 2017, the FERC audit staff issued its audit report which could have the potential to result in adjustments which could be material to Dominion Energy and Dominion Energy Gas’ results of operations. In December 2017, DETI provided its response to the audit report. DETI reached resolution of certain matters with FERC in the fourth quarter of 2018. Pending final resolution of the audit process and a determination by FERC, management is unable to estimate the potential impact of the remaining finding and no amounts have been recognized.

~~2017 Tax Reform Act~~

Other than the items discussed below, which are pending or have been resolved during the period, there have been no changes to the 2017 Tax Reform Act matters discussed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019.

In March 2019, Questar Gas filed with the Utah and Wyoming Commissions as to the impact of excess deferred income taxes resulting from the 2017 Tax Reform Act. Questar Gas proposed to return the 2018 amortization of excess deferred income taxes to customers and to incorporate the remaining excess deferred income tax impact in its next general rate cases in each jurisdiction. In March 2020, the Utah Commission issued an order approving Questar Gas’ proposal to refund the January 2019 through February 2020 amortization of excess deferred income taxes over 12 months beginning in June 2020. In April 2020, at the request of the Wyoming Commission, this matter was considered in conjunction with the base rate case that was filed in November 2019. In June 2020, the Wyoming Commission approved a proposal to share the benefits of deferred income taxes for the period January 2018 through August 2020 with customers over a one-year period beginning in September 2020. In addition, new base rates that go into effect in September 2020 will include the prospective impacts of sharing excess deferred income taxes with customers.

In October 2018, the Ohio Commission issued an order requiring rate-regulated utilities to file an application reflecting the impact of the 2017 Tax Reform Act on current rates by January 1, 2019. In December 2018, East Ohio filed its application proposing an approach to establishing rates and charges by and through which to return tax reform benefits to its customers. In December 2019, the Ohio Commission issued an order approving customer credits of approximately $600 million that will be shared with customers primarily over the remaining book life of the property to which the excess deferred income taxes relate. In addition, East Ohio will reduce rates approximately $19 million per year to account for the 2017 Tax Reform Act’s impact on its equity return component of rates charged to customers. A tax savings credit, which passes through the reduction in the federal income tax rate under the 2017 Tax Reform Act to customers in accordance with the settlement agreement approved by the Ohio Commission, became effective with the first billing cycle in April 2020.

Other Regulatory Matters

Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020.

Virginia Regulation

~~Virginia 2020 Legislation~~2021 Triennial Review

In April 2020, the Governor of Virginia signed into law the VCEA, which along with related legislation forms a comprehensive framework affecting Virginia Power’s operations. The VCEA replaces Virginia’s voluntary renewable energy portfolio standard forMarch 2021, Virginia Power ~~with a mandatory program setting annual renewable energy portfolio standard requirements based on~~filed its base rate case and accompanying schedules in support of the ~~percentage of total electric energy sold by~~2021 Triennial Review. In its filing, Virginia Power excluding existing nuclear generation and certain new carbon-free resources, reaching 100% by the end of 2045. The VCEA includes related requirements concerning deployment of wind, solar and energy storage resources, as well as provides for certain measures todid not request an increase ~~net-metering, including an allocation for low-income customers, incentivizes energy efficiency programs and directs Virginia to participate~~ in ~~a carbon trading program. While the legislation affects several portions of Virginia Power’s operations, key provisions of the GTSA remain in effect, including the triennial review structure~~

and timing, the use of the customer credit reinvestment offset and the $50 million cap on revenue reductions in the first triennial review proceeding. Key provisions of the VCEA and related legislation passed include the following:

~~FossilFuel Electric Generation~~: The legislation mandates Chesterfield Power Station Units 5 & 6 and Yorktown Power Station Unit 3 to be retired by the end of 2024, Altavista, Southampton and Hopewell to be retired by the end of 2028 and Virginia Power’s remaining fossil fuel units to be retired by the end of 2045, unless the retirement of such generating units will compromise grid reliability or security. The legislation also imposes a temporary moratorium on CPCNs for fossil fuel generation, unless the resources are needed for grid reliability. In addition, the Virginia Commission shall determine the amortization period for recovery of any appropriate costs due to the early retirement of any electric generation facilities, which could result in the reversal of previous retirement costs deemed recovered during the review period ending 2020. As discussed in Note 2, Virginia Power had recorded charges for early retirement of certain coal- and -oil fired generating units in the first quarters of 2020 and 2019. Virginia Power also revised the depreciable lives of Altavista, Southampton and Hopewell for the mandated retirement to the end of 2028, which will not have a material impact to Virginia Power’s results of operations or cash flows given the existing regulatory framework.

~~Renewable Generation:~~ The legislation provides a detailed renewable energy portfolio standard to achieve 100% zero-carbon generation by the end of 2045, excluding existing nuclear generation and certain new carbon-free resources. Components include requirements to petition the Virginia Commission for approval to construct or acquire new generating capacity to reach 16.1 GW of installed solar and onshore wind by the end of 2035, which includes specific requirements for utility-scale solar of 3.0 GW by the end of 2024, up to 15.0 GW by the end of 2035 and 1.1 GW of small-scale solar by the end of 2035. The legislation deems 2,700 MW of energy storage, including up to 800 MW for any one project which may include a pumped storage facility, by the end of 2035 to be in the public interest. The legislation also deems the construction or purchase of an offshore wind facility constructed off the Virginia coast with a capacity of up to 5,200 MW before 2035 to be in the public interest and provides certain presumptions facilitating cost recovery. The costs of such a facility constructed by the utility with a capacity between 2,500 and 3,000 MW will be presumed reasonably and prudently incurred if the Virginia Commission finds that the project meets competitive procurement requirements, the projected cost of the facility does not exceed a specified industry benchmark and the utility commences construction by the end of 2023 or has a plan for the facility to be in service by the end of 2027. The Virginia Commission must approve all projects to meet those requirements.

~~Energy Efficiency:~~The legislation includes an energy efficiency target of 5% energy savings, as measured from a 2019 baseline, through verifiable energy efficiency programs by the end of 2025 with future targets to be set by the Virginia Commission. Virginia Power has the opportunity to offset the lost revenues with margins on program spend if certain targets are achieved and can also seek recovery of the lost revenues associated with energy efficiency programs if such reductions are found to have caused Virginia Power to earn more than 50 basis points below a fair rate of return on its rates for generation and distribution services.

~~Carbon trading program~~: The legislation directs Virginia Power to participate in a market-based carbon trading program consistent with RGGI through 2050. All costs of the carbon trading program are recoverable through an environmental rider.

~~Low-income customers~~: The legislation includes the establishment of a percentage of income payment program to be administered by the Virginia Department of Housing and Community Development and the Virginia Department of Social Services. To fund the program, Virginia Power will remit amounts collected from customers under a universal service fee established and set by the Virginia Commission. As such, this program will not affect Virginia Power’s results of operations, financial position or cash flows.

Virginia Power expects to incur significant costs, including capital expenditures, to comply with the legislative requirements discussed above. The legislation allows for cost recovery under the existing or modified regulatory framework through rate adjustment clauses,base rates for generation and distribution services orand proposed that base rates remain at their existing level. Virginia Power’s ~~fuel factor,~~earnings test analysis, as filed, demonstrates it earned a combined ROE of 10.85% on its generation and distribution services for the test period, before accounting for forgiven customer balances. Pursuant to Virginia legislation, forgiven customer balances are excluded from the cost of service in determining test period revenues as part of the 2021 Triennial Review. To the extent that the Virginia Commission determines total earnings for the test period to be above Virginia Power’s authorized earnings band, the forgiven balance amounts are offset against the available revenues in the determination of any customer bill credits, or utilization of a CCRO. Test period earnings may be further reduced by Virginia Commission approved investment amounts in qualifying solar or wind generation facilities or electric distribution grid transformation projects that Virginia Power elects to include as a CCRO under the GTSA. In its filing, Virginia Power has elected to utilize $26 million of the Coastal Virginia Offshore Wind Pilot project investment as a CCRO to offset available revenues. The Virginia Commission will determine whether Virginia Power’s earnings for the test period, considered as a whole, were within 70 basis points above or below the authorized ROE of 9.2%. Should the Virginia Commission determine that there are additional available revenues for earnings sharing, then Virginia Power has contingently elected to offset those revenues with additional Virginia Commission approved qualifying CCRO investments. The Virginia Commission will also authorize an ROE for Virginia Power that will be applied to Virginia Power’s riders prospectively and that will also be utilized to measure base rate earnings as of January 1, 2021. Virginia Power is requesting authorization of an ROE of 10.8% based on Virginia Power’s current cost of equity. Pursuant to the Regulation Act, Virginia Power’s authorized ROE shall not be set lower than the average of either (i) the returns reported for the three previous years by not less than a majority of comparable utilities in the Southeastern U.S., with certain limitations as described in the Regulation Act, or (ii) the authorized returns that are set by the applicable regulatory commissions for the same select peer group. In May 2021, Virginia ~~Commission. Costs allocated~~Power filed supplemental testimony to reflect updated test period earnings, including an earned ROE of 10.42%, before accounting for forgiven customer balances, and that no amount of eligible CCRO is necessary to be elected to be utilized. This matter is pending.

In the third and fourth quarters of 2020, Virginia Power recorded a net charge of $130 million related to the ~~North Carolina jurisdiction will be recovered, subject to approval by the North Carolina Commission,~~use of a CCRO in accordance with the ~~existing regulatory framework.~~GTSA. In the first quarter of 2021, Virginia Power recorded a benefit of $130 million ($97 million after-tax) in impairment of assets and other charges in its Consolidated Statements of Income to adjust its reserve related to the use of a CCRO in accordance with the GTSA. These amounts reflect the impact related to jurisdictional customers as a result of the 2021 Triennial Review as well as the impact on certain non-jurisdictional customers which follow Virginia Power’s jurisdictional customer rate methodology.

Utility Disconnection Moratorium Legislation

In November 2020, legislation was enacted in Virginia relating to the moratorium on utility disconnections during the COVID-19 pandemic and resulted in Virginia Power forgiving Virginia jurisdictional retail electric customer balances that were more than 30 days past due as of September 30, 2020. As a result, Virginia Power recorded a charge of $127 million in the fourth quarter of 2020.

In connection with the Virginia 2021 budget process, in the first quarter of 2021 Virginia Power recorded a charge of $76 million ($56 million after-tax) in impairment of assets and other charges in its Consolidated Statements of Income for Virginia jurisdictional retail electric customer balances that were more than 30 days past due as of December 31, 2020 that Virginia Power is required to forgive. These forgiven customer balances are factored into Virginia Power’s 2021 Triennial Review as discussed above.

Grid Transformation and Security Act of 2018

In June 2021, Virginia Power filed a petition with the Virginia Commission for approval of a plan for electric distribution grid transformation projects as authorized by the GTSA. The plan includes 14 projects covering 6 components: (i) smart meters; (ii) customer information platform; (iii) grid improvement projects; (iv) physical and cyber security; (v) telecommunications infrastructure and (vi) customer education (Phase II). For Phase II, the total proposed capital investment during 2022 – 2023 is $669 million and the proposed operations and maintenance investment is $110 million. This matter is pending.

Virginia Fuel Expenses

In May 2021, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $1.4 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2021 and $72 million of estimated net under-recovered balances through June 30, 2021. In June 2021, the Virginia Commission approved the annual fuel factor.

Solar Facility Projects

In May 2020 and July 2020, Virginia Power entered into and closed on separate agreements to acquire Grassfield Solar, Norge Solar and Sycamore Solar. The projects are expected to cost approximately $170 million in aggregate once constructed, including the initial acquisition cost. The facilities are expected to generate 82 MW combined and be placed into service ~~by the end of~~in 2022. ~~Virginia Power expects to file with the Virginia Commission~~ ~~for CPCNs to construct and operate these projects as well as a rider to recover the costs associated with the recovery of certain renewable generation facilities in Virginia by the end of~~In October 2020,.

~~Grid Transformation and Security Act of 2018~~

In July 2018, Virginia Power filed a petition with the Virginia Commission for approval of the first three years of its ten-year plan for electric distribution grid transformation projects as authorized by the GTSA. During the first three years of the plan, Virginia Power proposed to focus on the following seven foundational components of the overall grid transformation plan: (i) smart meters; (ii)

customer information platform; (iii) reliability and resilience; (iv) telecommunications infrastructure; (v) cyber and physical security; (vi) predictive analytics; and (vii) emerging technology. The total estimated capital investment during 2019-2021 was $816 million and the proposed operations and maintenance expenses were $102 million. In January 2019, the Virginia Commission issued its final order approving capital spending for the first three years of the plan totaling $68 million on cyber and physical security and related telecommunications infrastructure (Phase IA). The Virginia Commission declined to approve the remainder of the proposed components for the first three years of the plan, the proposed spending for which was not found reasonable and prudent based on the record in the proceeding.

In September 2019, Virginia Power filed a revised plan which includes six components: (i) smart meters; (ii) customer information platform; (iii) grid improvement projects; (iv) telecommunications infrastructure; (v) cyber security; and (vi) a smart charging electric vehicle infrastructure pilot program (Phase IB). For Phase IB, the total proposed capital investment during 2019 – 2021 was $503 million and the proposed operations and maintenance investment was $78 million. In March 2020, the Virginia Commission issued an order approving $212 million of costs related to a new customer information platform, targeted grid hardening and corridor improvements, an electric vehicle Smart Charging Infrastructure Pilot Program, cyber security, stakeholder engagement and customer education and denied the costs associated with AMI, self-healing grid and certain other grid hardening projects alleging that Virginia Power did not prove the reasonableness and prudency of these costs. In April 2020, Virginia Power filed a petition for reconsideration of the Virginia Commission’s order and requested clarification of certain matters, including the Smart Charging Infrastructure Pilot Program. Additionally, Virginia Power requested clarification of certain matters relating to an AMI time-of-use rate and the smart charging electric vehicle infrastructure pilot program. Subsequently, in April 2020, the Virginia Commission denied in full Virginia Power’s petition for reconsideration; however, it stated that its March 2020 order contained all necessary approvals for the smart charging electric vehicle infrastructure pilot program. Virginia Power intends to file a revised plan that will address the elements needed for a comprehensive plan, as outlined by the Virginia Commission in its order.

~~Solar Facility Projects~~

~~In July 2019,~~ Virginia Power filed an application with the Virginia Commission for ~~a CPCN~~CPCNs to construct ~~Sadler Solar, which is estimated~~and operate these projects as part of its efforts to ~~cost approximately $146 million, excluding financing costs. Sadler Solar is expected to commence commercial operations, subject to regulatory approvals associated with~~meet the ~~project, in~~renewable generation development requirements under the fourth quarter of 2020. Virginia Power also applied for approval of Rider US-4 associated with this project with a proposed $9 million total revenue requirement for the rate year beginning June 1, 2020.VCEA. In January 2020, the Virginia Commission issued a final order granting the CPCN to construct Sadler Solar, subject to a 20- year performance guarantee of the facility at a 22% solar capacity factor when normalized for force majeure events. In March 2020, the Virginia Commission approved a $7 million total annual revenue requirement.

~~Virginia Fuel Expenses~~

In February 2020, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $1.2 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2020 and a projected over-recovery of approximately $81 million for the prior year balance as of June 30, 2020. Virginia Power requested that the new fuel factor rate be implemented on an interim basis two months early, beginning on May 1, 2020. In March 2020,April 2021, the Virginia Commission approved the interim rates. Virginia Power’s proposed fuel rate represents a fuel revenue decrease of approximately $393 million when applied to projected kilowatt-hour sales for the rate year beginning May 1, 2020. In June 2020, the Virginia Commission approved a revised fuel rate based on an updated projected over-recovery of $103 million for the prior year balance as of June 30, 2020.application.

~~Rate Adjustment Clauses~~Riders

Below is a discussion of significant riders associated with various Virginia Power projects:

•

The Virginia Commission previously approved Rider T1 concerning transmission rates. In May 2020, Virginia Power proposed a $1.0 billion total revenue requirement consisting of $474 million for the transmission component of Virginia Power’s base rates and $529 million for Rider T1 for the rate year beginning September 1, 2020. This total revenue requirement represents a $73 million increase versus the revenues to be produced during the rate year under current rates. In July 2020, the Virginia Commission approved the filing.

•

The Virginia Commission previously approved Riders C1A, C2A and C3A in connection with cost recovery for DSM programs. In December 2019, Virginia Power filed a petition to approve an additional 10 new energy efficiency programs and 1 new demand response DSM program for five years, subject to future extension, with a $186 million cost cap, and proposed a total $60 million revenue requirement for the rate year beginning September 1, 2020. This total revenue requirement represents an $11 million increase over the previous year. In July 2020, the Virginia Commission approved the filing.

•

The Virginia Commission previously approved Rider U in conjunction with cost recovery to move certain electric distribution facilities underground as authorized by Virginia legislation. In June 2020, Virginia Power proposed an $80 million total revenue requirement consisting of $44 million for previously approved phases and $36 million for phase five costs for Rider U for the rate year beginning April 1, 2021. This total revenue requirement represents a $28 million increase over the previous year. In February 2021, the Virginia Commission approved the filing.

In June 2021, Virginia Power proposed a $96 million total revenue requirement consisting of $61 million for previously approved phases and $35 million for phase six costs for Rider U for the rate year beginning April 1, 2022. This total revenue requirement represents a $16 million increase over the previous year. This matter is pending.

•

Pursuant to Virginia legislation, Virginia Power can recover the costs related to the closure of CCR units. In February 2021, Virginia Power filed for approval of Rider CCR with a proposed $216 million revenue requirement for the rate year beginning December 1, 2021. This matter is pending.

•

In October 2020, Virginia Power applied for approval of Rider CE associated with Grassfield Solar, Norge Solar and Sycamore Solar described above. In April 2021, the Virginia Commission approved a $10 million revenue requirement for the rate year beginning June 1, 2021.

•

The Virginia Commission previously approved Rider T1 concerning transmission rates. In May 2021, Virginia Power proposed a $874 million total revenue requirement consisting of $493 million for the transmission component of Virginia Power’s base rates and $381 million for Rider T1 for the rate year beginning September 1, 2021. This total revenue requirement represents a $190 million decrease versus the revenues to be produced during the rate year under current rates. This matter is pending.

•

Pursuant to the VCEA, Virginia Power can recover costs of compliance with the mandatory renewable portfolio standard program. In December 2020, Virginia Power filed for approval of Rider RPS with a proposed $13 million revenue requirement for the rate year beginning August 1, 2021. In July 2021, the Virginia Commission approved the filing.

•

The Virginia Commission previously approved Rider GV relating to Greensville County. In June 2021, Virginia Power proposed a biennial update procedure for Rider GV with two consecutive rate years. The filing proposed a revenue requirement of $142 million for the rate year beginning April 1, 2022 and a revenue requirement of $127 million for the rate year beginning April 2023. This matter is pending.

•

The Virginia Commission previously approved Rider R relating to Bear Garden. In June 2021, Virginia Power proposed a biennial update procedure for Rider R with two consecutive rate years. The filing proposed a revenue requirement of $59

million for the rate year beginning April 1, 2022 and a revenue requirement of $55 million for the rate year beginning April 1, 2023. This matter is pending.

•

The Virginia Commission previously approved Rider S relating to Virginia City Hybrid Energy Center. In June 2021, Virginia Power proposed a biennial update procedure for Rider S with two consecutive rate years. The filing proposed a revenue requirement of $192 million for the rate year beginning April 1, 2022 and a revenue requirement of $191 million for the rate year beginning April 1, 2023. This matter is pending.

•

Pursuant to Virginia legislation, Virginia Power can recover costs associated with participating in a market-based carbon trading program consistent with RGGI. In August 2021, the Virginia Commission approved Rider RGGI with a $168 million revenue requirement for the rate year beginning September 1, 2021.

Additional significant riders associated with various Virginia Power projects are as follows:

Rider Name

Application Date

Approval Date

Rate Year

Beginning

Total Revenue

Requirement

(millions)

Increase (Decrease)

Over Previous Year

(millions)

Application Date

Approval Date

Rate Year

Beginning

Total Revenue

Requirement

(millions)

Increase (Decrease)

Over Previous Year

(millions)

Rider US-3

July 2019

March 2020

June 2020

Rider BW

October 2019

June 2020

September 2020

(20

)

Rider US-2

October 2019

July 2020

September 2020

)

Rider B

June 2020

Pending

April 2021

)

June 2020

February 2021

April 2021

)

Rider GV

June 2020

Pending

April 2021

154

June 2020

February 2021

April 2021

153

Rider R

June 2020

Pending

April 2021

June 2020

February 2021

April 2021

Rider S

June 2020

Pending

April 2021

194

)

June 2020

February 2021

April 2021

194

)

Rider W

June 2020

Pending

April 2021

120

June 2020

February 2021

April 2021

120

Rider US-3

July 2020

Pending

June 2021

July 2020

March 2021

June 2021

Rider US-4

July 2020

Pending

June 2021

July 2020

March 2021

June 2021

Rider BW

October 2020

July 2021

September 2021

113

Rider US-2

October 2020

July 2021

September 2021

—

Rider B

June 2021

Pending

April 2022

)

Rider W

June 2021

Pending

April 2022

121

Rider US-3

August 2021

Pending

June 2022

Rider US-4

August 2021

Pending

June 2022

Electric Transmission Projects

In December 2019, Virginia Power filed an application with the Virginia Commission for a CPCN to construct a new Evergreen Mills switching station and add approximately one mile of overhead 230 kV double circuit transmission lines from both the existing Brambleton-Yardley Ridge line and Brambleton-Poland Road line in Loudoun County, Virginia, estimated to cost approximately $30 million. In May 2020, the Virginia Commission issued an order approving in part and denying in part the petition. The Virginia Commission approved Virginia Power’s request to construct the new Evergreen Mills switching station and the new 230 kV double circuit transmission line from the existing Brambleton-Yardley Ridge line with a total estimated cost of $25 million.

~~Additional Virginia Power electric transmission projects approved and applied for are as follows:~~

Description and Location
of Project

Application
Date

Approval
Date

Type of
Line

Miles of
Lines

Cost Estimate
(millions)
Rebuild and operate five segments between the Loudoun and Ox substations

August 2019

June 2020

230 kV

19

70
Rebuild and operate two lines in Chesterfield County, Virginia

January 2020

June 2020

230 kV

3

15
Bristers-Ladysmith Rebuild Project in the counties of Fauquier, Stafford, Spotsylvania, and Caroline, Virginia

May 2020

Pending

500 kV

37

110

Description and Location

of Project

Application

Date

Approval

Date

Type of

Line

Miles of

Lines

Cost Estimate

(millions)

Rebuild Clubhouse - Dry Bread Line and Dry Bread - Lakeview Line in Greensville County, Virginia

November 2020

July 2021

230 kV

Elmont-Ladysmith rebuild and related projects in the Counties of Hanover and Caroline, Virginia

April 2021

Pending

500 kV

Beaumeade-Belmont reconductor and rebuild projects in the County of Loudoun, Virginia

May 2021

Pending

230 kV

Extension to Cloud Switching Station and Easters Switching Station in the County of Mecklenburg, Virginia

June 2021

Pending

230 kV

105

North Carolina Regulation

~~North Carolina~~PSNC Base Rate Case

In ~~March 2019, Virginia Power~~April 2021, PSNC filed its ~~base~~general rate case application, direct testimony, exhibits, and schedules with the North Carolina Commission. ~~Virginia Power~~PSNC proposed a non-fuel, base rate increase of ~~$27~~$53 million to be effective November 1, ~~2019 on an interim basis subject~~2021. After considering the benefits of the 2017 Tax Reform Act, the net revenue increase to ~~refund, with any permanent rates ordered by the North Carolina Commission effective January 1, 2020.~~customers would be approximately $42 million. The base rate increase was proposed to recover the significant ~~investments~~investment in ~~generation,~~infrastructure to serve a growing customer base, improve safety and reliability of the transmission and distribution ~~infrastructure~~system and enhance energy efficiency and sustainability. The proposed rates would provide for ~~the benefit~~an ROE of ~~North Carolina customers. Virginia Power presented an earned return of 7.52% based upon a fully-adjusted test period,~~10.25% compared to ~~its~~the currently authorized 9.90% return, and proposed a 10.75% ROE. In September 2019, Virginia Power revised its filing to reduce the non-fuel base rate increase to $24 million. In January 2020, the North Carolina Commission approved a 9.75% ROE and disallowed certain costs associated with coal ash remediation at Chesterfield power station. In February 2020, the North Carolina Commission issued its final order relating to base rates. In July 2020, Virginia Power filed a notice of appeal and exceptions to the Supreme Court of North Carolina, arguing that the North Carolina Commission committed reversible error on certain issues relating to the ratemaking treatment of certain coal ash remediation costs.9.7%. This matter is pending.

~~Pipeline Integrity and Safety Program~~

The North Carolina Commission has authorized PSNC to use a tracker mechanism to recover the incurred capital investment and associated costs of complying with federal standards for pipeline integrity and safety requirements that are not in current base rates. In February 2020, the North Carolina Commission approved PSNC’s request to increase the integrity management annual revenue requirement to $28 million, an increase of $7 million over its previous filing, effective March 2020.

South Carolina Regulation

South Carolina Electric Base Rate Case

~~Pursuant~~In August 2020, DESC filed its retail electric base rate case and schedules with the South Carolina Commission. DESC proposed a non-fuel, base rate increase of $178 million, or 7.75%, based on an adjusted test year data, effective on or after the first billing cycle of

March 2021. The base rate increase was proposed to recover the significant investment in assets and operating resources required to serve an expanding customer base, maintain the safety, reliability and efficiency of DESC’s system and meet increasingly stringent reliability, security and environmental requirements for the benefit of South Carolina customers. DESC presented an earned ROE of 5.90% based upon a fully-adjusted test period. The proposed rates would provide for an earned ROE equal to the ~~SCANA Merger Approval Order,~~ current authorized earned ROE of ~~DESC will not file an application for a general~~10.25% established in the previous rate case in 2012. In January 2021, the South Carolina Commission approved a proposal made by the South Carolina Office of Regulatory Staff, and agreed to by DESC and other intervenors, to stay the base rate case due to the current economic conditions and to allow the parties more time to negotiate a settlement with a final order to be issued no later than August 2021.

In July 2021, DESC, the South Carolina Office of Regulatory Staff and other parties of record filed a comprehensive settlement agreement with the South Carolina Commission for approval. The comprehensive settlement agreement provides for a non-fuel, base rate increase of $62 million (resulting in a net increase of $36 million after considering an accelerated amortization of certain excess deferred income taxes) commencing with bills issued on September 1, 2021 and an authorized earned ROE of 9.50%. Additionally, DESC has agreed to commit up to $15 million to forgive retail electric customer balances that were more than 60 days past due as of May 31, 2021, and provide $15 million for energy efficiency upgrades and critical health and safety repairs to customer homes. Pursuant to the comprehensive settlement agreement, DESC would not filea ~~requested effective date for~~retail electric base rate case prior to July 1, 2023, such that new rates ~~earlier than~~would not be effective prior to January ~~2021.~~1, 2024, absent unforeseen extraordinary economic or financial conditions that may include changes in corporate tax rates. In ~~April 2020,~~July 2021, the South Carolina Commission voted to approve the comprehensive settlement agreement with a final order expected to be issued ~~an order vacating the portion of the SCANA Merger Approval Order requiring that new retail electric rates be implemented by January 1,~~in August 2021. ~~In July 2020, DESC filed a notice of intent with the South Carolina Commission to file for an increase to base rates for retail electric service no earlier than 30 days following the notice.~~ ~~The net lost revenue recovery portion of the DSM rider would be adjusted lower simultaneously with any approved retail electric base rate increases~~.

In connection with this matter, Dominion Energy recorded charges for both the three and six months ended June 30, 2021, of $249 million ($187 million after-tax) reflected within impairment of assets and other charges, including $237 million of regulatory assets associated with DESC’s purchases of its first mortgage bonds during 2019 that are no longer probable of recovery under the settlement agreement, and $18 million ($14 million after-tax) reflected within other income in its Consolidated Statements of Income.

DSM Programs

DESC has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In January ~~2020,~~2021, DESC filed an application with the South Carolina Commission seeking approval to recover ~~$40~~$48 million of costs and net lost revenues associated with these programs, along with an incentive to invest in such programs. In April ~~2020,~~2021, the South Carolina Commission approved the filing.

In connection with the approval of the comprehensive settlement agreement in the South Carolina base rate case discussed above, the net lost revenue component of the DSM rider will be adjusted resulting in a recovery of $43 million commencing with bills issued on September 1, 2021.

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 ~~2020,~~2021, DESC filed a proposal with the South Carolina Commission to ~~decrease~~increase the total fuel cost component of retail electric rates. DESC’s proposed ~~decrease~~adjustment would ~~reduce~~increase annual base fuel component recoveries by ~~$44~~$36 million and is ~~projected~~designed to ~~return to customers the existing over-collected balance while recovering~~recover DESC’s current base fuel costs, net of the existing over-collected balance, over the 12-month period beginning with the first billing cycle of May ~~2020.~~2021. In addition, DESC proposed a decrease to its variable environmental component and an increase to its ~~variable environmental and~~ distributed energy resource ~~components.~~component. In April ~~2020,~~2021, the South Carolina Commission approved the filing.

~~Electric Transmission Projects~~

In 2020, DESC began several electric transmission projects in connection with two new nuclear plants under development by Southern. These transmission projects are required to be in place prior to these plants beginning operations to maintain reliability. DESC anticipates the projects to go into service in phases, costing approximately $75 million in aggregate. In February 2020, DESC filed an application with the South Carolina Commission requesting approval to construct and operate 28 miles of 230 kV transmission lines in Aiken County, South Carolina estimated to cost approximately $30 million. In June 2020, the South Carolina Commission approved the filing.

Natural Gas Rates

In June ~~2020,~~2021, DESC filed with the South Carolina Commission its monitoring report for the 12-month period ended March 31, ~~2020~~2021 with a total revenue requirement of ~~$409~~$426 million. This represents a $9 million overall annual increase to its natural gas rates under the terms of the Natural Gas Rate Stabilization Act effective with the first billing cycle of November ~~2020.~~2021. This matter is pending.

Ohio Regulation

PIR Program

In 2008, East Ohio began PIR, aimed at replacing approximately 25% of its pipeline system. In April ~~2020,~~2021, the Ohio Commission approved East Ohio’s application to adjust the PIR cost recovery rates for 2020 costs. The filing reflects gross plant investment for 2020 of $178 million, cumulative gross plant investment of $2.0 billion and an annual revenue requirement of $243 million.

CEP Program

In 2011, East Ohio began CEP which enables East Ohio to defer depreciation expense, property tax expense and carrying costs associated with CEP investments. In April 2021, East Ohio filed an application requesting approval to adjust the CEP cost recovery rates for 2019 and 2020 costs. The filing reflects gross plant investment for 2019 of ~~$209~~$137 million, gross plant investment for 2020 of $99 million, cumulative gross plant investment of ~~$1.8 billion~~$957 million and a revenue requirement of $119 million. This matter is pending.

UEX Rider

East Ohio has approval for a UEX Rider through which it recovers the bad debt expense of most customers not participating in the PIPP Plus Program. The UEX Rider is adjusted annually to achieve dollar for dollar recovery of East Ohio’s actual write-offs of uncollectible amounts. In May 2021, East Ohio filed an application with the Ohio Commission requesting approval of its UEX Rider to reflect an increased annual revenue requirement of ~~$218 million.~~

$20 million to provide for an under-recovered accumulated bad debt expense of $7 million as of March 31, 2021, and recovery of net bad debt expense projected to total $13 million for the twelve-month period ending March 2022. In July 2021, the Ohio Commission approved the filing.

West Virginia Regulation

West Virginia Base Rate Case

In September 2020, Hope filed its base rate case and schedules with the West Virginia Commission. Hope proposed a non-fuel, base rate increase of $28 million. The base rate increase was proposed to recover the significant investment in distribution infrastructure and costs associated with the acquisition of over 2,000 miles of gathering assets, both for the benefit of West Virginia customers. The proposed rates would provide for an ROE of 10.25% compared to the authorized ROE of 9.45%. In July 2021, the West Virginia Commission approved a non-fuel, base rate increase of $13 million for rates effective July 2021 with an ROE of 9.54%.

PREP

In May ~~2020,~~2021, Hope filed a PREP application with the West Virginia Commission requesting approval to recover PREP costs related to ~~$39~~$54 million and ~~$54~~$56 million of projected capital investment for ~~2020~~2021 and ~~2021,~~2022, respectively. The application also includes a true-up of PREP costs related to the ~~2019~~2020 actual capital investment of ~~$27~~$34 million and sets forth ~~$13~~$9 million of annual PREP costs to be recovered in proposed rates effective November 1, ~~2020.~~2021. This matter is pending.

~~Wyoming~~Utah Regulation

~~Wyoming Base Rate Case~~Purchased Gas

In ~~November 2019, Questar Gas filed its base rate case and schedules with~~May 2021, the Wyoming Commission. Questar Gas proposed a non-fuel, base rate increase of $4 million effective September 2020. The base rate increase was proposed to replace aging infrastructure and expand its system. Questar Gas presented an earned return of 7.46%, based upon a fully-adjusted test period, compared to its authorized 9.5% return, and proposed a 10.5% ROE. In June 2020, the WyomingUtah Commission approved Questar Gas’ request for a ~~base rate~~$43 million gas cost increase ~~of $2 million annually,~~ with rates effective ~~September 1, 2020. This revenue requirement increase is based on an approved ROE of 9.35%.~~

~~FERC – Gas~~

~~Cove Point~~

In January 2020, pursuant to the terms of a previous settlement, Cove Point filed a general rate case for its FERC-jurisdictional services, with proposed rates to be effective March 1, 2020. Cove Point proposed an annual cost-of-service of approximately $182 million. In February 2020, FERC approved suspending the changes in rates for five months following the proposed effective date, until August 1, 2020, subject to refund.

~~In February 2020, Cove Point submitted its annual electric power cost adjustment to FERC requesting approval to recover $28 million. FERC approved the adjustment in March 2020.~~

~~Overthrust~~

In May 2020, Overthrust filed an application to request FERC authorization to construct, operate and maintain the Wamsutter West Expansion project to provide 120,000 Dth per day of new capacity flowing east to west from the Wamsutter interconnect to the Opal interconnect. The project facilities are expected to commence commercial operations in the fourth quarter of 2020 and are expected to cost $10 million. FERC approved the application in July 2020.

~~DETI~~

~~In January 2018, DETI filed an application to request FERC authorization to construct and operate certain facilities located in Ohio and Pennsylvania for the Sweden Valley project. In~~ June 2019, DETI withdrew its application for the project due to certain regulatory delays. As a result of the project abandonment, during the second quarter of 2019, DETI recorded a charge of $13 million ($10 million after-tax), included in impairment of assets and other charges in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income.2021.

Note 14. 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, ~~2019.~~2020.

Dominion Energy’s Consolidated Statements of Income include $55 million and $89 million for the three and six months ended June 30, 2021, respectively, and $53 million and $85 million for the three and six months ended June 30, 2020, respectively, ~~and $53 million and $82 million for the three and six months ended June 30, 2019, respectively,~~ of rental revenue included in operating revenue. Dominion Energy’s Consolidated Statements of Income include $31 million and $58 million for the three and six months ended June 30, 2021, respectively, and $27 million and $50 million for the three and six months ended June 30, 2020, ~~respectively, and $24 million and $47 million for the three and six months ended June 30, 2019,~~ respectively, of depreciation expense included in depreciation, depletion and amortization, related to facilities subject to power purchase agreements under which Dominion Energy is the lessor.

Corporate Office Leasing Arrangement

In December 2019, Dominion Energy signed an agreement with a lessor, as amended in May 2020, to construct and lease a new corporate office property in Richmond, Virginia. The lessor ~~is providing~~provided equity and ~~has~~had obtained financing commitments from debt investors, totaling $465 million, to fund the estimated project costs. IfIn March 2021, Dominion Energy ~~ultimately proceeds with~~notified the ~~project through completion,~~lessor of its intention to terminate the ~~project is expected~~leasing arrangement effective April 2021. As a result, Dominion Energy recorded a charge of $71 million ($53 million after-tax) in the first quarter of 2021, included in impairments of assets and other charges in its Consolidated Statements of Income, primarily for amounts required to be completed by September 2024. Dominion Energy has been appointed to act as the construction agent for the lessor, during which time Dominion Energy will request cash draws from the lessor and debt investors to fund all project costs. If the project is terminated under certain events, Dominion Energy could be required to pay up to 100% of the then funded amount.

The lease term will commence once construction is substantially complete and the facility is able to be occupied and end in December 2027. At the end of the initial lease term, Dominion Energy can (i) extend the term of the lease for an additional five years, subjectrepaid 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, up to 83% of project costs, for the difference between the project costs and sale proceeds. Dominion Energy is not considered the owner during construction for financial accounting purposes and, therefore, will not reflect the construction activity in its consolidated financial statements. Dominion Energy expects to recognize a right-of-use asset and a corresponding finance lease liability at the commencement of the lease term. Dominion Energy will be considered the owner of the leased property for tax purposes, and as a result, will be entitled to tax deductions for depreciation and interest expense.lessor.

Note 15. 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, ~~2019.~~2020.

Dominion Energy

At June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, Dominion Energy’s securities due within one year included ~~$32~~$35 million and ~~$31~~$32 million, respectively, and at June 30, 2021 and December 31, 2020, Dominion Energy’s long-term debt included ~~$258~~$228 million and ~~$267~~$239 million, respectively, of debt issued by SBL Holdco, a VIE, net of issuance costs, that is nonrecourse to Dominion Energy and is secured by SBL Holdco’s interest in certain merchant solar facilities.

Virginia Power

Virginia Power had a long-term power and capacity contract with 1 non-utility generator with an aggregate summer generation capacity of approximately 218 MW. In May 2019, Virginia Power entered into an agreement and paid $135 million to terminate the remaining contract with the non-utility generator, effective April 2019. A $135 million ($100 million after-tax) charge was recorded in impairment of assets and other charges in Virginia Power’s Consolidated Statements of Income for the three and six months ended June 30, 2019. Virginia Power paid $13 million for electric capacity and $1 million for electric energy to the non-utility generator in the six months ended June 30, 2019.

~~Dominion Energy Gas~~

Dominion Energy Gas purchased shared services from DECGS and DEQPS of $3 million and $7 million for the three months ended June 30, 2020, $5 million and $11 million for the three months ended June 30, 2019, $7 million and $14 million for the six months ended June 30, 2020, and $9 million and $20 million for the six months ended June 30, 2019, respectively. Dominion Energy Gas’ Consolidated Balance Sheets included amounts due to both DECGS and DEQPS of $18 million and $15 million at June 30, 2020 and December 31, 2019, respectively.

~~Virginia Power and Dominion Energy Gas~~

~~Virginia Power and Dominion Energy Gas~~ purchased shared services from DES, an affiliated VIE, of ~~$86~~$93 million and ~~$27~~$86 million for the three months ended June 30, 2021 and 2020, respectively, and ~~$129~~$189 million and ~~$39 million for the three months ended June 30, 2019,~~ $179 ~~million and $58~~ million for the six months ended June 30, ~~2020~~2021 and ~~$218 million and $67 million for the six months ended June 30, 2019,~~2020, respectively. Virginia Power’s Consolidated Balance Sheets include amounts due to DES of ~~$92~~$129 million and ~~$102~~$175 million at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, recorded in payables to affiliates. ~~Dominion Energy Gas’ Consolidated Balance Sheets include amounts due to DES of $38 million and $27 million at June 30, 2020 and December 31, 2019, respectively, recorded in payables to affiliates.~~

Note 16. 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 commodity prices, hedging levels, Dominion Energy’s credit ratings and the credit quality of its counterparties.

Dominion Energy

In June 2021, Dominion Energy amended its $6.0 billion joint revolving credit facility to provide for a discount in the pricing of certain annual fees and amounts borrowed by Dominion Energy under the facility if Dominion Energy achieves certain annual renewable electric generation and diversity and inclusion objectives. In addition, the amended facility incorporates certain administrative changes with respect to the anticipated transition from LIBOR to an alternative benchmark rate. The key financial covenants are unchanged from the previous facility.

At June 30, ~~2020,~~2021, Dominion Energy’s commercial paper and letters of credit outstanding, as well as its capacity available under the credit facility, were as follows:

Facility

Limit

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

Facility

Capacity

Available

Facility

Limit

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

Facility

Capacity

Available

(millions)

Joint revolving credit facility⁽¹⁾

6,000

210

103

5,687

6,000

2,636

3,265

(1)

This credit facility matures in ~~March 2023~~June 2026, with the potential to be extended by the borrowers to June 2028, 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 $2.0 billion of letters of credit.

~~In addition to the credit facility mentioned above, Dominion Energy also has a credit facility which had an original stated maturity date of~~ ~~June 2020~~ and allowed Dominion Energy to issue up to approximately $21 million in letters of credit. In May 2020, the credit facility was amended to increase the facility capacity to approximately $30 million and extend the maturity date to ~~June 2022. At June 30, 2020, Dominion Energy had $21 million in letters of credit outstanding under this agreement.~~

In March 2020, Dominion Energy entered into a $900 million 364-Day Revolving Credit Agreement. The agreement bears interest at a variable rate. At June 30, 2020, $225 million was outstanding under the agreement. The proceeds from these borrowings were used to provide for general working capital and other general corporate purposes. The maximum allowed total debt to total capital ratio under the agreement is consistent with such allowed ratio under Dominion Energy’s joint revolving credit facility.

DESC and Questar Gas’ short-term financings are supported through access as co-borrowers to the joint revolving credit facility discussed above with ~~Dominion Energy, Virginia Power and Dominion Energy Gas.~~the Companies. At June 30, ~~2020,~~2021, the sub-limits for DESC and Questar Gas were $500 million and $250 million, respectively.

In January ~~2020,~~2021, DESC and GENCO applied to FERC for a two-year short-term borrowing authorization. In March ~~2020,~~2021, FERC granted DESC authority through March ~~2021~~2023 to issue short-term indebtedness (pursuant to Section 204 of the Federal Power Act) in amounts not to exceed $2.2 billion outstanding with maturity dates of one year or less. In addition, in March ~~2020,~~2021, FERC granted GENCO authority through March ~~2021~~2023 to issue short-term indebtedness not to exceed $200 million outstanding with maturity dates of one year or less.

In addition to the credit facilities mentioned above, Dominion Energy also has a credit facility which allows Dominion Energy to issue up to approximately $30 million in letters of credit and matures in June 2022. At June 30, 2021 and December 31, 2020, Dominion Energy had $29 million and $30 million in letters of credit outstanding under this agreement, respectively.

In addition to the credit facilities mentioned above, SBL Holdco has $30 million of credit facilities which had an original stated maturity date of December 2017 with automatic one-year renewals through the maturity of the SBL Holdco term loan agreement in 2023. Dominion Solar Projects III, Inc. has $25 million of credit facilities which had an original stated maturity date of May 2018 with automatic one-year renewals through the maturity of the Dominion Solar Projects III, Inc. term loan agreement in 2024. At both June 30, 2021 and December 31, 2020, 0 amounts were outstanding under either of these facilities.

In March 2020, Dominion Energy ~~borrowed $500~~entered into a $900 million ~~under a~~ 364-Day ~~Term Loan Credit Agreement that bears interest at a variable rate.~~ The proceeds were used to provide for general working capital and other general corporate purposes. These borrowings are presented within securities due within one year in Dominion Energy’s Consolidated Balance Sheets at June 30, 2020. The maximum allowed total debt to total capital ratio under the agreement is consistent with such allowed ratio under Dominion Energy’s joint revolving credit facility.

~~In April 2020, Dominion Energy borrowed $625 million under a 364-Day Term Loan~~Revolving Credit Agreement that bore interest at a variable rate. ~~The proceeds were used to provide for general working capital~~At December 31, 2020, $225 million was outstanding under the agreement. In March 2021, the agreement reached maturity and ~~other general corporate purposes. In June 2020,~~ Dominion Energy repaid the outstanding ~~balance~~borrowed amount in full.

In ~~November 2017,~~July 2021, Dominion Energy ~~filed a SEC~~entered into an approximately $1.3 billion term loan credit agreement following the termination of the Q-Pipe Transaction as discussed in Note 3.

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 Investment^SM~~. The registration limits~~ as disclosed in Note 17 to the ~~principal~~

~~amount that may be outstanding at any one time to $1.0 billion. The notes are offered~~Consolidated Financial Statements in the Companies’ Annual Report on ~~a continuous basis and bear interest at a floating rate per annum determined by~~Form 10-K for 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. year ended December 31, 2020. At June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, Dominion Energy’s Consolidated Balance Sheets include ~~$176~~$392 million and ~~$75~~$268 million, respectively, with respect to such notes presented within short-term debt. The proceeds are used for general corporate purposes and to repay debt.

Virginia Power

Virginia Power’s short-term financing is supported through its access as co-borrower to ~~the~~Dominion Energy’s $6.0 billion joint revolving credit ~~facility. This credit~~facility, as amended in June 2021. The facility can be used for working capital, as support for the combined commercial paper programs of ~~the borrowers under the credit facility~~Virginia Power, Dominion Energy, Questar Gas and DESC and for other general corporate purposes.

At June 30, ~~2020,~~2021, Virginia Power’s share of commercial paper and letters of credit outstanding under ~~its~~the joint revolving credit facility with Dominion Energy, ~~Dominion Energy Gas,~~ Questar Gas and DESC was as follows:

Facility

Limit⁽¹⁾

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

Facility

Limit⁽¹⁾

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

(millions)

Joint revolving credit facility⁽¹⁾

6,000

—

6,000

814

(1)

The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, ~~Dominion Energy Gas,~~ Questar Gas and DESC. The sub-limit for Virginia Power is set ~~within~~pursuant to the terms of the facility ~~limit~~ but can be changed at the option of the borrowers ~~under the credit facility~~ multiple times per year. At June 30, ~~2020,~~2021, the sub-limit for Virginia Power was ~~$1.5~~$1.75 billion. If Virginia Power has liquidity needs in excess of its 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 ~~March 2023 and~~June 2026, with the potential to be extended by the borrowers to June 2028. The credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $2.0 billion (or the sub-limit, whichever is less) of letters of credit.

~~Dominion Energy Gas~~

Dominion Energy Gas’ short-term financing is supported through its access as co-borrower to the joint revolving credit facility. This credit facility can be used for working capital, as support for the combined commercial paper programs of the borrowers under the credit facility and for other general corporate purposes.

At June 30, 2020, Dominion Energy Gas' share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Virginia Power, Questar Gas and DESC was as follows:

Facility
Limit⁽¹⁾

Outstanding
Commercial
Paper

Outstanding
Letters of
Credit

(millions)

Joint revolving credit facility⁽¹⁾

$
1,500

$
—

$
—

~~(1)~~

A maximum of $1.5 billion of the facility is available to Dominion Energy Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion Energy, Virginia Power, Questar Gas and DESC. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the borrowers under the credit facility multiple times per year. At June 30, 2020, the sub-limit for Dominion Energy Gas was $750 million. If Dominion Energy Gas has liquidity needs in excess of its 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 March 2023 and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion (or the sub-limit, whichever is less) of letters of credit.

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 2020,~~March 2021, PSNC issued, through private placement, $150 million of 3.10% senior notes that mature in 2051.

In April 2021, Dominion Energy issued $600 million of 1.45% senior notes and $500 million of 3.30% senior notes that mature in 2026 and 2041, respectively.

In June 2021, Questar Gas entered into an agreement with certain investors to issue through private placement in August 2021, $125 million 2.21% 10-year senior notes and $125 million 3.15% 30-year senior notes.

In June 2021, Dominion Energy entered into a $900 million Sustainability Revolving Credit Agreement. This supplemental credit facility, which matures in June 2024 and bears interest at a variable rate, offers a reduced interest rate margin with respect to borrowed amounts allocated to certain environmental sustainability or social investment initiatives. Proceeds of the supplemental credit facility also may be used for general corporate purposes, but such proceeds are not eligible for a reduced interest rate margin. At June 30, 2021, $250 million was outstanding under the supplemental credit facility. The proceeds from these borrowings were used to support environmental sustainability and social investment initiatives. The maximum allowed total debt to total capital ratio under this supplemental credit facility is consistent with such allowed ratio under Dominion Energy’s joint revolving credit facility.

In July 2021, DESC redeemed the remaining principal outstanding of $30 million of its 3.22% first mortgage bonds, plus accrued interest. The bonds would have otherwise matured in October 2021.

In July 2021, Dominion Energy redeemed the remaining principal outstanding of ~~$111 million and $286~~$400 million of its ~~June 2006 hybrids and its September 2006 hybrids, respectively, both which would have otherwise matured in 2066. All purchases were~~

conducted in compliance with the applicable RCC, each of which was terminated in February 2020. Expenses related to the early redemption of the hybrids were $10 million reflected within interest and related charges in the Consolidated Statements of Income for the six months ended June 30, 2020.

~~In March 2020, SCANA redeemed its floating rate~~2.0% senior notes, ~~at the remaining principal balance of $66 million~~ plus accrued interest. The notes would have otherwise matured in August 2021.

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 June ~~2034. Expenses related~~30, 2021 and December 31, 2020, Dominion Energy had issued and outstanding 2.4 million shares of preferred stock, 1.6 million and 0.8 million of which were designated as the Series A Preferred Stock and the Series B Preferred Stock, respectively. Dominion Energy’s Series A Preferred Stock and Series B Preferred Stock are described in Note 19 to the ~~early redemption~~Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2020.

Dominion Energy recorded dividends of ~~the senior notes were~~ $7 million ~~reflected within interest~~($4.375 per share) for both the three months ended June 30, 2021 and ~~related charges in the Consolidated Statements of Income~~2020, and $14 million ($8.750 per share) for both the six months ended June 30, ~~2020.~~

In March 2020, SCANA redeemed the remaining principal outstanding of $183 million of its 4.75% medium-term notes and $155 million of its 4.125% medium-term notes plus accrued interest and make-whole premiums. The notes would have otherwise matured in May 2021 and ~~February 2022, respectively. Total expenses related to~~2020, on the ~~early redemption~~Series A Preferred Stock. Dominion Energy also recorded dividends of $9 million ($11.625 per share) for both the ~~medium-term notes were $14~~three months ended June 30, 2021 and 2020, and $18 million ~~reflected within interest and related charges in the Consolidated Statements of Income~~($23.250 per share) for both the six months ended June 30, ~~2020.~~

~~In March~~2021 and 2020, ~~Dominion Energy issued $400 million of 3.30% senior notes and $350 million of 3.60% senior notes that mature in 2025 and 2027, respectively.~~

~~In March 2020, PSNC issued, through private placement, $200 million of 4.05% senior notes that mature in 2030.~~

~~In April 2020, Dominion Energy issued $1.5 billion of 3.375% senior notes that mature in 2030.~~

In April 2020, Dominion Energy purchased and canceled $7 million of its 2.579% junior subordinated notes that mature in July 2020. In June 2020, Dominion Energy prepaid the remaining balance of $993 million.

In June 2020, East Ohio issued, through private placement, $500 million of 1.30% senior notes, $500 million of 2.00% senior notes and $800 million of 3.00% senior notes that mature in 2025, 2030 and 2050, respectively. East Ohio used the proceeds from this offering to repay intercompany promissory noteson Series B Preferred Stock. The stock purchase contract liability associated with Dominion ~~Energy Gas and a portion of its intercompany revolving credit agreement balance with Dominion Energy.~~

In June 2020, Virginia Power remarketed 1 series of tax-exempt bonds, with an aggregate outstanding principal of $105 million to new investors. The bonds will bear interest at a coupon rate of 1.20% until May 2024, after which they will bear interest at a market rate to be determined at that time.

~~Derivative Restructuring~~

In June 2020, Dominion Energy amended a portfolio of interest rate swaps with a notional value of $2.0 billion, extending the mandatory termination dates from 2020 and 2021 to December 2024. The transaction is viewed as a non-cash financing activity with an embedded interest rate swap. As a result, in June 2020, Dominion Energy recorded $326 million in other long-term debt, representing the net present value of the initial fair value measurement of the new contract with an imputed interest rate of 1.19%, in its Consolidated Balance Sheets with an embedded interest rate derivative that had a fair value of zero at inception.

~~Noncontrolling Interest in Dominion Energy Midstream~~

In January 2019, Dominion Energy and Dominion Energy Midstream closed on an agreement and plan of merger pursuant to which Dominion Energy acquired each outstanding common unit representing limited partner interests in Dominion Energy Midstream not already owned by Dominion Energy through the issuance of 22.5 million shares of common stock valued at $1.6 billion. Under the terms of the agreement and plan of merger, each publicly held outstanding common unit representing limited partner interests in Dominion Energy Midstream was converted into the right to receive 0.2492 shares of Dominion Energy common stock. Immediately prior to the closing, each Series A Preferred Unit representing limited partner interests in Dominion Energy Midstream was converted into common units representing limited partner interests in Dominion Energy Midstream in accordance with the terms of Dominion Energy Midstream’s partnership agreement. The merger was accounted for by Dominion Energy following the guidance for a change in a parent company’s ownership interest in a consolidated subsidiary. Because Dominion Energy controls Dominion Energy Midstream both before and after the merger, the changes in Dominion Energy’s ownership interest in Dominion Energy Midstream were accounted for as an equity transaction and 0 gain or loss was recognized. In connection with the merger, Dominion Energy recognized $40 million of income taxes in equity primarily attributable to establishing additional regulatory liabilities related to excess deferred income taxes and changes in state income taxes.

~~2019 Corporate Units~~

~~In June 2019, Dominion Energy issued $1.6 billion of~~ 2019 Equity Units ~~initially in the form of 2019 Series A Corporate Units. The Corporate Units are listed on the NYSE under the symbol DCUE. The net proceeds were used for general corporate purposes~~was $87 million and ~~to repay short-term debt, including commercial paper.~~

~~Each 2019 Series A Corporate Unit consists of a stock purchase contract~~$129 million at June 30, 2021 and a 1/10, or 10%, undivided beneficial ownership interest in one share of Series A Preferred Stock. Beginning in June 2022, the Series A Preferred Stock is convertible at the option of the holder into Dominion Energy common stock under a formula based upon the average closing price of Dominion Energy common stock prior to the conversion date. The Series A Preferred Stock is redeemable in cash by Dominion Energy beginning September 2022 at the liquidation preference. Settlement of any conversion is payable in cash, common stock or a combination thereof, at Dominion Energy’s election.

The stock purchase contracts obligate the holders to purchase shares of Dominion Energy common stock in June 2022. The purchase price to be paid under the stock purchase contracts is $100 per Corporate Unit and the number of shares to be purchased will be determined under a formula based upon the average closing price of Dominion Energy common stock near the settlement date. The Series A Preferred Stock was pledged upon issuance as collateral to secure the purchase of common stock under the related stock purchase contracts.

Dominion Energy pays cumulative dividends on the Series A Preferred Stock and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. Dominion Energy may elect to pay such dividends and/or payments in cash, shares of Dominion Energy common stock or a combination of cash and shares of Dominion Energy common stock. Dominion Energy may defer the contract adjustment payments for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, Dominion Energy may not make any distributions related to its capital stock, including dividends, redemptions, repurchases or liquidation payments. Also, during the deferral period, Dominion Energy may not make any payments on or redeem, repay or repurchase any debt securities that are equal in right of payment with, or subordinated to, the contract adjustment payments or make any payment on any guarantee of a security of a subsidiary if the guarantee ranks equal or junior to the contract adjustment payments. Unless all accumulated and unpaid dividends on the Series A Preferred Stock have been declared and paid, Dominion Energy may not make any distributions on any of its capital stock ranking equal or junior to the Series A Preferred Stock as to dividends or upon liquidation, as applicable, including dividends, redemptions, repurchases or liquidation payments. In such circumstances, Dominion Energy also may not make any contract adjustment payments or other similar types of payments, subject to certain exceptions.

~~Dominion Energy has recorded the present value of the stock purchase contract payments as a liability offset to common stock.~~December 31, 2020, respectively. Stock purchase contract payments ~~are recorded against this liability. Accretion~~ of $42 million and $41 million were made during the ~~stock purchase contract liability is recorded as imputed interest expense.~~six months ended June 30, 2021 and 2020, respectively. In calculating diluted EPS, Dominion Energy applies the treasury stock method to the stock purchase contracts and the if-converted method to the Series A Preferred Stock. ~~Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, the maximum number of shares of common stock Dominion Energy will issue in June 2022 is 21.8 million.~~

~~Selected information about Dominion Energy’s 2019 Equity Units is presented below:~~

Issuance Date

Units Issued

Total Net
Proceeds⁽¹⁾

Total
Preferred
Stock⁽²⁾

Cumulative
Dividend
Rate

Stock
Purchase
Contract
Annual Rate

Stock
Purchase
Contract
Liability⁽³⁾

Stock Purchase
Contract
Settlement Date
(millions except interest rates)

6/14/2019

16

$
1,582

$
1,610

1.75
%

5.5
%

$
250

6/1/2022

~~(1)~~

~~Issuance costs of $28 million were recorded as a reduction to preferred stock ($14 million) and common stock ($14 million) in the Consolidated Balance Sheets.~~

~~(2)~~

~~Dominion Energy recorded dividends of $7 million ($4.375 per share) and $14 million ($8.750 per share) for the three and six months ended June 30, 2020, respectively.~~

~~(3)~~

Payments of $41 million were made during the six months ended June 30, 2020. The stock purchase contract liability was $171 million and $212 million at June 30, 2020 and December 31, 2019, respectively.

~~Series B Preferred Stock~~

In December 2019, Dominion Energy issued 800,000 shares of Series B Preferred Stock for $791 million, net of $9 million of issuance costs. The preferred stock has a liquidation preference of $1,000 per share and currently pays a 4.65% dividend per share on the liquidation preference. Dividends are paid cumulatively on a semi-annual basis, commencing June 15, 2020. Dominion Energy recorded dividends of $9 million ($11.625 per share) and $18 million ($23.250 per share) for the three and six months ended June 30, 2020, respectively. The dividend rate for the Series B Preferred Stock will be reset every five years beginning on December 15, 2024 to equal the then-current five-year U.S. Treasury rate plus a spread of 2.993%. Unless all accumulated and unpaid dividends on the Series B Preferred Stock have been declared and paid, Dominion Energy may not make any distributions on any of its capital stock ranking equal or junior to the Series B Preferred Stock as to dividends or upon liquidation, including through dividends, redemptions, repurchases or otherwise.

Dominion Energy may, at its option, redeem the Series B Preferred Stock in whole or in part on December 15, 2024 or on any subsequent fifth anniversary of such date at a price equal to $1,000 per share plus any accumulated and unpaid dividends. Dominion Energy may also, at its option, redeem the Series B Preferred Stock in whole but not in part at a price equal to $1,020 per share plus any accumulated and unpaid dividends at any time within a certain period of time following any change in the criteria ratings agencies use to assign equity credit to securities such as the Series B Preferred Stock that has certain adverse effects on the equity credit actually received by the Series B Preferred Stock.

Holders of the Series B Preferred Stock have no voting rights except in the limited circumstances provided for in the terms of the Series B Preferred Stock or as otherwise required by applicable law. The Series B Preferred Stock is not subject to any sinking fund or other obligation of Dominion Energy’s to redeem, repurchase or retire the Series B Preferred Stock. The preferred stock contains no conversion rights.

Issuance of Common Stock

~~See~~Dominion Energy recorded, net of fees and commissions, $97 million from the issuance of 1 million shares of common stock for the six months ended June 30, 2021 and $148 million from the issuance of 2 million shares of common stock for the six months ended June 30, 2020, through various programs including Dominion Energy Direct® and employee savings plans as described in Note 320 to the Consolidated Financial Statements to the Companies’ Annual Report on Form 10-K for ~~information on~~ the ~~issuance of~~year ended December 31, 2020.

In July 2021, Dominion Energy ~~common stock in January 2019 in connection with the SCANA Combination. Also in January 2019, Dominion Energy acquired all outstanding partnership interests~~issued 1.4 million shares of ~~Dominion Energy Midstream not owned by Dominion Energy through the issuance of common stock as noted above.~~

Dominion Energy maintains Dominion Energy Direct® and a number of employee savings plans through which contributions may be invested in Dominion Energy’s common stock. These shares may either be newly issued or purchased on the open market with proceeds contributed to these plans. In April 2014, Dominion Energy began issuing new common shares for these direct stock purchase plans. In August 2020, Dominion Energy began purchasing its common stock, onvalued at $104 million, to satisfy DESC’s obligation under a settlement agreement for the ~~open market~~FILOT litigation discussed in Note 17.

In August 2021, Dominion Energy issued 0.6 million shares of its common stock, valued at $45 million, to satisfy DESC’s obligation for ~~these direct stock purchase plans.~~

the initial payment under a settlement agreement with the SCDOR discussed in Note 17.

At-the-Market Program

In ~~June 2017,~~August 2020, Dominion Energy ~~filed an SEC shelf registration statement for the sale of debt and equity securities including the ability~~entered into sales agency agreements to ~~sell common stock through~~effect sales under an at-the-market program as discussed in Note 20 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019. In March 2020,~~2020. As of June 30, 2021, Dominion Energy has not issued any shares or entered into ~~four separate sales agency~~any forward sale agreements to effect sales under a new at-the-market program and pursuant to which it had the ability to offer from time to time up to $500 million aggregate amount of its common stock. Dominion Energy did 0t issue any shares under this ~~new program which expired in June 2020.~~

program.

Repurchase of Common Stock

In ~~July~~November 2020, the Board of Directors authorized the repurchase of up to ~~$3.0~~$1.0 billion of Dominion Energy’s common stock and rescinded the prior two authorizations from 2005 and 2007. The repurchase program does not include a specific timetable 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.

~~Dividend Restrictions~~

~~At June 30, 2020, DESC’s retained earnings exceed the balance established by the Federal Power Act~~ as a reserve on earnings attributable to hydroelectric generation plants. As a result, DESC is permitted to pay dividends without additional regulatory approval provided that such amounts would not bring the retained earnings balance below the threshold. There have been no other significant changes to dividend restrictions affecting the Companies describeddiscussed in Note ~~21,~~20 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020. Dominion Energy did 0t repurchase any shares of common stock during the six months ended June 30, 2021.

Note 17. 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. 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

~~CAA~~

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, states are required to establish regulatory programs to ~~address all~~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.

~~MATS~~

~~In February 2019, the EPA published a proposed rule to reverse its previous finding that it is appropriate and necessary to regulate hazardous air pollutant emissions from~~ ~~coal- and oil-fired electric generating units~~. In May 2020, the EPA’s final rule became effective. The final rule is consistent with the EPA’s February 2019 proposal, and determines that it is not appropriate and necessary to regulate mercury and hazardous air pollutant emissions from coal- and oil-fired electric generating units. The final rule also states that the MATS rule remains in place and the emissions standards for affected coal- and oil-fired electric generating units will not change. ~~Dominion Energy and Virginia Power are complying with the applicable requirements of the rule and do not expect any impacts to their operations.~~

Ozone Standards

The EPA published final non-attainment designations for the October 2015 ozone standard in June ~~2018. States have until August 2021~~2018 with states required to develop plans to address the new standard. Until the states have developed implementation plans for the standard, 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 and cash flows.

~~Oil and Gas NSPS~~

In August 2012, the EPA issued an NSPS impacting new and modified facilities in the natural gas production and gathering sectors and made revisions to the NSPS for natural gas processing and transmission facilities. These rules establish equipment performance specifications and emissions standards for control of VOC emissions for natural gas production wells, tanks, pneumatic controllers and compressors in the upstream sector. In June 2016, the EPA issued another NSPS regulation, for the oil and natural gas sector, to regulate methane and VOC emissions from new and modified facilities in transmission and storage, gathering and boosting, production and processing facilities. All projects which commenced construction after September 2015 are required to comply with this regulation. In October 2018, the EPA published a proposed rule reconsidering and amending portions of the 2016 rule, including but not limited to, the fugitive emissions requirements at well sites and compressor stations. The amended portions of the 2016 rule

were effective immediately upon publication. Until the proposed rule regarding reconsideration is final, Dominion Energy and Dominion Energy Gas are implementing the 2016 regulation. Dominion Energy and Dominion Energy Gas are still evaluating whether potential impacts on results of operations, financial condition and/or cash flows related to this matter will be material.

ACE Rule

In July 2019, the EPA published the final rule informally referred to as the ACE Rule, as a replacement for the Clean Power Plan. The ACE Rule ~~applies to~~regulated GHG emissions from existing coal-fired power ~~plants. The final rule includes unit-specific performance standards based on~~plants pursuant to Section 111(d) of the ~~degree of emission reduction levels achievable from unit efficiency improvements to be determined by the permitting agency. The ACE Rule requires~~CAA and required states to develop plans by July 2022 establishing unit-specific performance standards for existing coal-fired power plants. In January 2021, the U.S. Court of Appeals for the D.C. Circuit vacated the ACE Rule and remanded it to ~~implement these performance standards. These state plans must be approved by~~the EPA. This decision would take effect upon issuance of the court’s mandate. In March 2021, the court issued a partial mandate vacating and remanding all parts of the ACE Rule except for the portion of the ACE Rule that repealed the Clean Power Plan. While the EPA ~~by January 2024. While~~has stated its intention to replace the ~~impacts of~~ACE Rule, it is unknown at this ~~rule could be material to Dominion Energy~~time if or how the EPA will issue a replacement for the ACE Rule and ~~Virginia Power’s results of~~how that replacement will affect the Companies’ 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.~~

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 ~~to set~~exceed a significant emissions rate atof 75,000 tons per year of CO₂ equivalent ~~emissions under which a source would not be required to apply BACT for its GHG~~ 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.

In December 2018, the EPA proposed revised Standards of Performance for Greenhouse Gas Emissions from New, Modified, and Reconstructed Stationary Sources. The proposed rule would amend the previous determination that the best system of emission reduction for newly constructed coal-fired steam generating units is no longer partial carbon capture and storage. Instead, the proposed revised best system of emission reduction for this source category is the most efficient demonstrated steam cycle (e.g., supercritical steam conditions for large units and subcritical steam conditions for small units) in combination with ~~the~~ best operating practices.

~~State Regulations~~

In ~~May 2019, VDEQ issued~~January 2021, the EPA published a final rule ~~establishing~~affirming that fossil fuel-fired electric generating units meet the requirement that a ~~state carbon regulation program with~~source category “significantly contribute” to endangering air pollution for the purposes of regulating GHG emissions from new, modified and reconstructed stationary sources. The January 2021 rule also established a 28.0 million ton initial state-wide carbon cap in 2020. The cap was to be reduced by approximately 3 percent per year through 2030, resulting in an ultimate cap of 19.6 million tons. The final rule included a provisionthreshold for ~~VDEQ to delay implementation of~~ the ~~rule pending authorization from the General Assembly~~“significant contribution” threshold that would have meant that no other source category, such as oil and ~~Governor of Virginia.~~gas facilities, petroleum refineries, and boilers, would meet that requirement at this time. In April ~~2020, Virginia legislation was enacted authorizing VDEQ~~2021, the U.S. Court of Appeals for the D.C. Circuit granted an unopposed motion by the EPA to ~~implement~~vacate and remand the ~~final~~January 2021 rule. ~~In June 2020, the VDEQ signed the CO~~₂ ~~Budget Trading Program rule outlining the requirements for Virginia’s participation in RGGI starting in 2021.~~ The ~~regulatory framework in Virginia provides rate recovery mechanisms that are expected to substantially mitigate any such impact.~~

~~The legislation discussed above is considered related legislation~~proposed revision to the ~~VCEA as discussed in Note 13. The VCEA institutes a mandatory renewable portfolio standard, enhances renewable generation and energy storage development, requires~~performance standards for coal-fired steam generating units remains pending. Until the ~~retirement~~EPA ultimately takes final action on this rulemaking, the Companies cannot predict the impact to their results of ~~certain generation facilities, establishes energy efficiency targets, expands net metering and directs Virginia’s participation in a market-based carbon trading program through 2050.~~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 5 mandatory facility-specific factors, including a social cost-benefit test, and 6 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 1315 and 79 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 ~~six~~eight hydroelectric facilities, including ~~one~~three Virginia Power ~~facility. Dominion Energy anticipates~~facilities. The Companies anticipate that itthey may have to install impingement control technologies at certain of these stations that have once-through cooling systems. ~~Dominion Energy and Virginia Power~~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, technology, cost and 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 ~~Dominion Energy and Virginia Power’s~~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.

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 ~~establishes~~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 2 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 ~~remains~~was December ~~2023.~~ 2023. In October 2020, the EPA released the final rule that extends the latest dates for compliance. Individual facilities’ compliance dates will vary based on circumstances and the determination by state regulators and may range from 2021 to 2028. While the impacts of this rule could be material to ~~Dominion Energy and Virginia Power’s~~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.

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, ~~Dominion Energy, Virginia Power or Dominion Energy Gas~~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 1112 sites associated with Dominion Energy, including certain sites acquired in the SCANA Combination, 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 ~~or expects to propose~~ remediation plans associated with 3 sites, including 1 at Virginia Power, and expects to ~~conduct~~commence remediation activities ~~primarily by the end~~in 2021 or 2022 depending on receipt of ~~2021.~~final permits and approvals. At ~~both~~ June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, Dominion Energy ~~and Virginia Power have $34~~had $40 million and ~~$16~~$42 million, respectively, and Virginia

Power had $25 million and $26 million, respectively, of reserves recorded. In addition, for 1 site associated with Dominion Energy, an updated work plan submitted to SCDHEC in September 2018, would increase costs by approximately $11 million if approved by federal and state agencies. In September 2020, this plan was submitted to the Army Corps of Engineers. Dominion Energy is associated with 1312 additional sites, including 2 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, ~~Dominion Energy and Virginia Power~~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 potential financial statement impacts; however, they could have a material impact on results of operations, financial condition and/or cash flows.

SCANA Legal Proceedings

The following describes certain legal proceedings involving Dominion Energy, SCANA or DESC relating to events occurring before closing of the SCANA Combination. No reference to, or disclosure of, any proceeding, item or matter described below shall be construed as an admission or indication that such proceeding, item or matter is material. For certain of these matters, and unless otherwise noted therein, Dominion Energy is unable to estimate a reasonable range of possible loss and the related financial statement impacts, but for any such matter there could be a material impact to its results of operations, financial condition and/or cash flows. For the matters for which Dominion Energy is able to reasonably estimate a probable loss, Dominion Energy’s Consolidated Balance Sheets at June 30, ~~2020~~2021 and December 31, ~~2019~~2020 include reserves of ~~$538~~ $341million and ~~$696 million, respectively, and insurance~~

~~receivables of $8 million and $111~~$208 million, respectively, included within other current liabilities, and insurance receivables of $56 million and $8 million, respectively, included within other receivables. During the three and six months ended June 30, 2021, Dominion Energy’s Consolidated Statements of Income include charges of $40 million ($30 million after-tax) and $100 million ($75 million after-tax), respectively, included within impairment of assets and other charges. During the six months ended June 30, 2020, Dominion Energy’s Consolidated Statements of Income include charges of $25 million ($25 million after-tax) included within other income (expense). ~~During the three and six months ended June 30, 2019, Dominion Energy’s Consolidated Statements of Income include charges of $100 million ($75 million after-tax) and $278~~ ~~million ($208 million after-tax), respectively, included within impairment of assets and other charges.~~

Ratepayer Class Actions

In May 2018, a consolidated complaint against DESC, SCANA and the State of South Carolina was filed in the State Court of Common Pleas in Hampton County, South Carolina (the DESC Ratepayer Case). ~~In September 2018, the court certified this case as a class action.~~ The plaintiffs ~~allege,~~alleged, among other things, that DESC was negligent and unjustly enriched, breached alleged fiduciary and contractual duties and committed fraud and misrepresentation in failing to properly manage the NND Project, and that DESC committed unfair trade practices and violated state anti-trust laws. The plaintiffs sought a declaratory judgment that DESC may not charge its customers for any past or continuing costs of the NND Project, sought to have SCANA and DESC’s assets frozen and all monies recovered from Toshiba Corporation and other sources be placed in a constructive trust for the benefit of ratepayers and sought specific performance of the alleged implied contract to construct the NND Project.

In December 2018, the State Court of Common Pleas in Hampton County entered an order granting preliminary approval of a class action settlement. The court entered an order granting final approval of the settlement ~~and a stay of pre-trial proceedings~~ in ~~the DESC Ratepayer Case.~~June 2019, which became effective in July 2019. The settlement agreement, contingent upon the closing of the SCANA Combination, provided that SCANA and DESC ~~would~~ establish an escrow account and proceeds from the escrow account would be distributed to the ~~class members,~~plaintiffs, after payment of certain taxes, attorneys' fees and other expenses and administrative costs. The escrow account would include (1) up to $2.0 billion, net of a credit of up to $2.0 billion in future electric bill relief, which would inure to the benefit of the escrow account in favor of class members over a period of time established by the South Carolina Commission in its order related to matters before the South Carolina Commission related to the NND Project, (2) a cash payment of $115 million and (3) the transfer of certain DESC-owned real estate or sales proceeds from the sale of such properties, which counsel for the ~~DESC Ratepayer Class estimate~~plaintiffs estimated to have an aggregate value between $60 million and $85 million. At the closing of the SCANA Combination, SCANA and DESC funded the cash payment portion of the escrow account. ~~The court held a fairness hearing on the settlement in May 2019. In June 2019, the court entered an order granting final approval of the settlement, which order became effective July 2019.~~ In July 2019, DESC transferred $117 million representing the cash payment, plus accrued interest, to the plaintiffs. ~~In addition,~~Through August 2020, property, plant and equipment with a net recorded value of ~~$54~~$27 million ~~is in the process of being~~had been transferred to the plaintiffs in coordination with the court-appointed real estate trustee to satisfy the settlement ~~agreement,~~agreement. In September 2020, the court entered an order approving a final resolution of the transfer of real estate or sales proceeds with a cash contribution of $38.5 million by DESC and the conveyance of property, plant and equipment with a net recorded value of $3 million, which ~~$26 million had been transferred as of June 30,~~was completed by DESC in October 2020.

In September 2017, a purported class action was filed by Santee Cooper ratepayers against Santee Cooper, DESC, Palmetto Electric Cooperative, Inc. and Central Electric Power Cooperative, Inc. in the State Court of Common Pleas in Hampton County, South Carolina (the Santee Cooper Ratepayer Case). The allegations ~~are~~were substantially similar to those in the DESC Ratepayer Case. The plaintiffs seek a declaratory judgment that the defendants may not charge the purported class for reimbursement for past or future costs of the NND Project. In March 2018, the plaintiffs filed an amended complaint including as additional named defendants, including certain then current and former directors of Santee Cooper and SCANA. In June 2018, Santee Cooper filed a Notice of Petition for Original Jurisdiction with the Supreme Court of South Carolina. In December 2018, Santee Cooper filed its answer to the plaintiffs' fourth amended complaint and filed cross claims against DESC, which was denied. In October 2019, Santee Cooper voluntarily consented to stay its cross claims against DESC pending the outcome of the trial of the underlying case. In November 2019, DESC removed the case to the U.S. District Court for the District of South Carolina. In December 2019, the plaintiffs and Santee Cooper filed a motion to remand the case to state court. In January 2020, the case was remanded to state court. In March 2020, the parties executed a settlement agreement relating to this matter as well as the Luquire Case and the Glibowski Case described below. The settlement agreement ~~provides~~provided that Dominion Energy and Santee Cooper ~~will~~ establish a fund for the benefit of class members in the amount of $520 million, of which Dominion Energy’s portion iswas $320 million of shares of Dominion Energy common stock. ~~Also in March 2020, the court granted preliminary approval for the settlement agreement.~~ In July 2020, the court issued a final approval of the settlement agreement. ~~The~~In September 2020, Dominion Energy issued $322 million of shares of Dominion Energy common stock to satisfy its obligation under the settlement ~~will become effective upon the expiration of a 30-day appellate period. This case is pending.~~agreement, including interest charges.

In July 2019, a similar purported class action was filed by certain Santee Cooper ratepayers against DESC, SCANA, Dominion Energy and former directors and officers of SCANA in the State Court of Common Pleas in Orangeburg, South Carolina (the Luquire Case). In August 2019, DESC, SCANA and Dominion Energy were voluntarily dismissed from the case. The claims ~~are~~were similar to the Santee Cooper Ratepayer Case. In March 2020, the parties executed a settlement agreement as described above relating to this matter as well as the Santee Cooper Ratepayer Case and the Glibowski Case. This case ~~will be~~was dismissed ~~upon the effective date~~as part of the Santee Cooper Ratepayer Case ~~settlement. This case is pending.~~settlement described above.

RICO Class Action

In January 2018, a purported class action was filed, and subsequently amended, against SCANA, DESC and certain former executive officers in the U.S. District Court for the District of South Carolina (the Glibowski Case). The plaintiff ~~alleges,~~alleged, among other things, that SCANA, DESC and the individual defendants participated in an unlawful racketeering enterprise in violation of RICO and conspired to violate RICO by fraudulently inflating utility bills to generate unlawful proceeds. The DESC Ratepayer Class Action settlement described previously contemplates dismissal of claims by DESC ratepayers in this case against DESC, SCANA and their officers. In August 2019, the individual defendants filed motions to dismiss. In March 2020, the parties executed a settlement agreement as described above relating to this matter as well as the Santee Cooper Ratepayer Case and the Luquire Case. This case ~~will be~~was dismissed ~~upon the effective date~~as part of the Santee Cooper Ratepayer Case ~~settlement. This case is pending.~~settlement described above.

SCANA Shareholder Litigation

In September 2017, a purported class action was filed against SCANA and certain former executive officers and directors in the U.S. District Court for the District of South Carolina. Subsequent additional purported class actions were separately filed against all or nearly all of these defendants (collectively the SCANA Securities Class Action). In January 2018, the U.S. District Court for the District of South Carolina consolidated these suits, and the plaintiffs filed a consolidated amended complaint in March 2018. The plaintiffs ~~allege,~~alleged, among other things, that the defendants violated §10(b) of the Securities Exchange Act of 1934, as amended, and Rule 10b-5 promulgated thereunder, and that the individually named defendants are liable under §20(a) of the same act. In June 2018, the defendants filed motions to dismiss. In March 2019, the U.S. District Court for the District of South Carolina granted in part and denied in part the defendants’ motions to dismiss. In December 2019, the parties executed a settlement agreement pursuant to which SCANA ~~will~~would pay $192.5 million, up to $32.5 million of which ~~can~~could be satisfied through the issuance of shares of Dominion Energy common stock, subject to ~~approval by the U.S. District Court for the District of South Carolina.~~court approval. In February 2020, the U.S. District Court for the District of South Carolina granted preliminary approval of the settlement agreement, pending a fairness ~~hearing.~~hearing, and granted final approval in July 2020. In March 2020, SCANA funded an escrow account with $160 million in cash and ~~the balance of the settlement will be paid upon final approval of the settlement by the court. In July 2020, the court granted final approval of the settlement agreement. In August 2020, SCANA~~ paid the balance of $32.5 million in cash in August 2020 to satisfy the settlement.

In September 2017, a shareholder derivative action was filed against certain former executive officers and directors of SCANA in the State Court of Common Pleas in Richland County, South ~~Carolina.~~Carolina (the State Court Derivative Case). In September 2018, this action was consolidated with another action in the Business Court Pilot Program in Richland County. The plaintiffs allege, among other things, that the defendants breached their fiduciary duties to shareholders by their gross mismanagement of the NND Project, and that the defendants were unjustly enriched by bonuses they were paid in connection with the project. In January 2019, the defendants filed a motion to dismiss the consolidated action. In February 2019, one action was voluntarily dismissed. In March 2020, the court denied the defendants’ motion to dismiss. In April 2020, the defendants filed a notice of appeal with the South Carolina Court of Appeals and a petition with the Supreme Court of South Carolina seeking appellate review of the denial of the motion to dismiss. In June 2020, the plaintiffs filed a motion to dismiss the appeal with the South Carolina Court of Appeals, which was granted in July 2020. In August 2020, the Supreme Court of South Carolina denied the defendants’ petition seeking appellate review. Also in August 2020, the defendants filed a petition for rehearing with the South Carolina Court of Appeals relating to the July 2020 ruling by the court, which was denied in October 2020. In November 2020, SCANA filed a petition of certiorari with the Supreme Court of South Carolina seeking appellate review of the denial of SCANA’s motion to dismiss. This ~~case is pending.~~

petition was denied in June 2021. Also in June 2021, the parties reached an agreement in principle in the amount of $33 million to resolve this matter, subject to court approval. This settlement was reached in contemplation of and will be utilized to satisfy a portion of the Federal Court Merger Case and the State Court Merger Case discussed below.

In January 2018, a purported class action was filed against SCANA, Dominion Energy and certain former executive officers and directors of SCANA in the State Court of Common Pleas in Lexington County, South Carolina (the City of Warren Lawsuit). The plaintiff alleges, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that would unfairly deprive plaintiffs of the true value of their SCANA stock, and that Dominion Energy aided and abetted these actions. Among other remedies, the plaintiff seeks to enjoin and/or rescind the merger. In February 2018, Dominion Energy removed the case to the U.S. District Court for the District of South Carolina, and filed a Motion to Dismiss in March 2018. In June 2018, the case was remanded back to the State Court of Common Pleas in Lexington County. Dominion Energy appealed the decision to remand to the U.S. Court of Appeals for the Fourth Circuit, where the appeal was consolidated with a similar appeal in the Metzler Lawsuit discussed below. In June 2019, the U.S. Court of Appeals for the Fourth Circuit reversed the order remanding the case to state court.

~~In February 2018,~~ a purported class action was filed against Dominion Energy and certain former directors of SCANA and DESC in the State Court of Common Pleas in Richland County, South Carolina (the Metzler Lawsuit). The allegations made and the relief sought by the plaintiffs are substantially similar to that described for the City of Warren Lawsuit. In February 2018, Dominion Energy removed the case to the U.S. District Court for the District of South Carolina, and filed a Motion to Dismiss in March 2018. In August 2018, the case was remanded back to the State Court of Common Pleas in Richland County. Dominion Energy appealed the decision to remand to the U.S. Court of Appeals for the Fourth Circuit, where the appeal was consolidated with the City of Warren Lawsuit. In June 2019, the U.S. Court of Appeals for the Fourth Circuit reversed the order remanding the case to state court.

In September 2019, the U.S. District Court for the District of South Carolina granted the plaintiffs’ motion to consolidate the City of Warren Lawsuit and the Metzler ~~Lawsuit.~~Lawsuit (the Federal Court Merger Case). In October 2019, the plaintiffs filed an amended complaint against certain former directors and executive officers of SCANA and DESC, which stated substantially similar allegations to those in the City of Warren Lawsuit and the Metzler Lawsuit as well as an inseparable fraud claim. In November 2019, the defendants filed a motion to dismiss. In April 2020,

the U.S. District Court for the District of South Carolina denied the motion to ~~dismiss~~.dismiss. In May 2020, SCANA filed a motion to ~~intervene.~~intervene, which was denied in August 2020. In

September 2020, SCANA filed a notice of appeal with the U.S. Court of Appeals for the Fourth Circuit. In June 2021, the parties reached an agreement in principle in the amount of $63 million to resolve this matter as well as the State Court Merger Case described below, subject to court approval. This ~~case is pending.~~settlement was reached in contemplation of and will be partially satisfied by the State Court Derivative Case settlement described above.

In May 2019, a case was filed against certain former executive officers and directors of SCANA in the State Court of Common Pleas in Richland County, South ~~Carolina.~~Carolina (the State Court Merger Case). The plaintiff alleges, among other things, that the defendants breached their fiduciary duties to shareholders by their gross mismanagement of the NND Project, were unjustly enriched by the bonuses they were paid in connection with the project and breached their fiduciary duties to secure and obtain the best price for the sale of SCANA. Also in May 2019, the case was removed to the U.S. District Court of South Carolina by the non-South Carolina defendants. In June 2019, the plaintiffs filed a motion to remand the case to state court. In January 2020, the case was remanded to state court. In February 2020, the defendants filed a motion to dismiss. ~~This case is pending.~~In June 2021, the parties reached an agreement in principle as described above relating to this matter as well as the Federal Court Merger Case and the State Court Derivative Case.

Employment Class Actions and Indemnification

In August 2017, a case was filed in the U.S. District Court for the District of South Carolina on behalf of persons who were formerly employed at the NND Project. In July 2018, the court certified this case as a class action. In February 2019, certain of these plaintiffs filed an additional case, which case has been dismissed and the plaintiffs have joined the case filed August 2017. The plaintiffs allege, among other things, that SCANA, DESC, Fluor Corporation and Fluor Enterprises, Inc. violated the Worker Adjustment and Retraining Notification Act in connection with the decision to stop construction at the NND Project. The plaintiffs allege that the defendants failed to provide adequate advance written notice of their terminations of employment and are seeking damages, which could be as much as $100 million for 100% of the NND Project. In January 2021, the U.S. District Court for the District of South Carolina granted summary judgment in favor of SCANA, DESC, Fluor Corporation and Fluor Enterprises, Inc. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fourth Circuit. This case is pending.

In September 2018, a case was filed in the State Court of Common Pleas in Fairfield County, South Carolina by Fluor Enterprises, Inc. and Fluor Daniel Maintenance Services, Inc. against DESC and Santee Cooper. The plaintiffs make claims for indemnification, breach of contract and promissory estoppel arising from, among other things, the defendants' alleged failure and refusal to defend and indemnify the Fluor defendants in the aforementioned case. ~~These cases are~~This case is pending.

FILOT Litigation and Related Matters

In November 2017, Fairfield County filed a complaint and a motion for temporary injunction against DESC in the State Court of Common Pleas in Fairfield County, South Carolina, making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of implied duty of good faith and fair dealing and unfair trade practices related to DESC’s termination of the FILOT agreement between DESC and Fairfield County related to the NND Project. The plaintiff sought a temporary and permanent injunction to prevent DESC from terminating the FILOT agreement. The plaintiff withdrew the motion for temporary injunction in December 2017. ~~This case is pending.~~In July 2021, the parties executed a settlement agreement requiring DESC to pay $99 million, which could be satisfied in either cash or shares of Dominion Energy common stock. Also in July 2021, the State Court of Common Pleas in Fairfield County, South Carolina approved the settlement. In July 2021, Dominion Energy issued 1.4 million shares of Dominion Energy common stock to satisfy DESC’s obligation under the settlement agreement.

Governmental Proceedings and Investigations

In June 2018, DESC received a notice of proposed assessment of approximately $410 million, excluding interest, from the SCDOR following its audit of DESC’s sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The proposed assessment, which includes 100% of the NND Project, is based on the SCDOR’s position that DESC’s sales and use tax exemption for the NND Project does not apply because the facility will not become operational. In December 2020, the parties reached an agreement in principle in the amount of $165 million to resolve this matter. In June 2021, the parties executed a settlement agreement which allows DESC ~~has protested~~to fund the ~~proposed assessment, which remains pending.~~settlement amount through a combination of cash, shares of Dominion Energy common stock or real estate with an initial payment of at least $43 million in shares of Dominion Energy common stock. In August 2021, Dominion Energy issued 0.6 million shares of its common stock to satisfy DESC’s obligation for the initial payment under the settlement agreement.

In September and October 2017, SCANA was served with subpoenas issued by the U.S. Attorney’s Office for the District of South Carolina and the Staff of the SEC’s Division of Enforcement seeking documents related to the NND Project. In February 2020, the SEC filed a complaint against SCANA, two of its former executive officers and DESC in the U.S. District Court for the District of South Carolina alleging that the defendants violated federal securities laws by making false and misleading statements about the NND Project. In April 2020, SCANA and DESC reached an agreement in principle with the Staff of the SEC’s Division of Enforcement to settle, without admitting or denying the allegations in the complaint. ~~The Staff~~In December 2020, the U.S. District Court for the District of

South Carolina issued an order approving the ~~SEC’s Division of Enforcement has not yet presented the proposed~~ settlement ~~to the SEC. The agreement in principle would, among other things, require~~which required SCANA to pay a civil monetary penalty totaling $25 million, and SCANA and DESC to pay disgorgement and prejudgment interest totaling $112.5 million, which disgorgement and prejudgment interest amount ~~will be~~were deemed satisfied by the settlements in the SCANA Securities Class Action and the DESC Ratepayer Case. SCANA paid the civil penalty in December 2020. The ~~proposed settlement is contingent on the review and approval~~SEC civil action against two former executive officers of ~~final documentation by~~ SCANA ~~DESC and the Staff of the SEC’s Division of Enforcement~~remains pending and is currently subject to ~~approval~~a stay granted by the ~~SEC and~~court in June 2020 at the ~~U.S. District Court for the District~~request of ~~South Carolina. In June 2020,~~ the U.S. Attorney’s Office for the District of South Carolina filed a motion to intervene and stay the SEC civil action, which the court granted. The stay is currently in effect but does not preclude the SEC’s Division of Enforcement from presenting the proposed settlement with SCANA and DESC to the SEC. This matter is pending.Carolina.

In addition, the South Carolina Law Enforcement Division is conducting a criminal investigation into the handling of the NND Project by SCANA and DESC. Dominion Energy is cooperating fully with the investigations by the U.S. Attorney’s Office and the South Carolina Law Enforcement Division, including responding to additional subpoenas and document requests. Dominion Energy has also entered into a cooperation agreement with the U.S. Attorney’s Office and the South Carolina Attorney General’s Office. The cooperation agreement provides that in consideration of its full cooperation with these investigations to the satisfaction of both agencies, neither such agency will criminally prosecute or bring any civil action against Dominion Energy or any of its current, previous, or future direct or indirect subsidiaries related to the NND Project. A former executive officer of SCANA entered a plea agreement with the U.S. Attorney’s Office and the South Carolina Attorney General’s Office in June 2020 and entered a guilty plea with the U.S. District Court for the District of South Carolina in July 2020. ~~These matters are pending.~~

~~Other Litigation~~

~~In December 2018, arbitration proceedings commenced between DESC~~Another former executive officer of SCANA entered a plea agreement with the U.S. Attorney's Office and ~~Cameco Corporation~~the South Carolina Attorney General's Office in November 2020 and entered guilty pleas in the U.S. District Court for the District of South Carolina and in South Carolina state court in February 2021. As a result of the pleas, Dominion Energy has terminated indemnity for these former executive officers related to a supply agreement signed in May 2008. This agreement provides the terms and conditions under which DESC agreed to purchase uranium hexafluoride from Cameco Corporation over a period from 2010 to 2020. Cameco Corporation alleges that DESC violated this agreement by failing to purchase the stated quantities of uranium hexafluoride for the 2017 and 2018 delivery years. DESC denies that it is in breach of the agreement and believes that it has reduced its purchase quantity within the terms of the agreement. This matter is pending.these two cases.

Abandoned NND Project

DESC, for itself and as agent for Santee Cooper, entered into an engineering, construction and procurement contract with Westinghouse and WECTEC in 2008 for the design and construction of the NND Project, of which DESC’s ownership share is 55%. Various difficulties were encountered in connection with the project. The ability of Westinghouse and WECTEC to adhere to established budgets and construction schedules was affected by many variables, including unanticipated difficulties encountered in connection with project engineering and the construction of project components, constrained financial resources of the contractors, regulatory, legal, training and construction processes associated with securing approvals, permits and licenses and necessary amendments to them within projected time frames, the availability of labor and materials at estimated costs and the efficiency of project labor. There were also contractor and supplier performance issues, difficulties in timely meeting critical regulatory requirements, contract disputes, and changes in key contractors or subcontractors. These matters preceded the filing for bankruptcy protection by Westinghouse and WECTEC in March 2017, and were the subject of comprehensive analyses performed by SCANA and Santee Cooper.

Based on the results of SCANA’s analysis, and in light of Santee Cooper's decision to suspend construction on the NND Project, in July 2017, SCANA determined to stop the construction of the units and to pursue recovery of costs incurred in connection with the construction under the abandonment provisions of the Base Load Review Act or through other means. This decision by SCANA became the focus of numerous legislative, regulatory and legal proceedings. Some of these proceedings remain unresolved and are described above.

In September 2017, DESC, for itself and as agent for Santee Cooper, filed with the U.S. Bankruptcy Court for the Southern District of New York Proofs of Claim for unliquidated damages against each of Westinghouse and WECTEC. These Proofs of Claim were based upon the anticipatory repudiation and material breach by Westinghouse and WECTEC of the contract, and assert against Westinghouse and WECTEC any and all claims that are based thereon or that may be related thereto.

Westinghouse’s reorganization plan was confirmed by the U.S. Bankruptcy Court for the Southern District of New York and became effective in August 2018. In connection with the effectiveness of the reorganization plan, the contract associated with the NND Project was deemed rejected. DESC is contesting approximately $285 million of filed liens in Fairfield County, South Carolina. Most of these asserted liens are claims that relate to work performed by Westinghouse subcontractors before the Westinghouse bankruptcy, although some of them are claims arising from work performed after the Westinghouse bankruptcy.

Westinghouse has indicated that some unsecured creditors have sought or may seek amounts beyond what Westinghouse allocated when it submitted its reorganization plan to the U.S. Bankruptcy Court for the Southern District of New York. If any unsecured creditor is successful in its attempt to include its claim as part of the class of general unsecured creditors beyond the amounts in the bankruptcy reorganization plan allocated by Westinghouse, it is possible that the reorganization plan will not provide for payment in full or nearly in full to its pre-petition trade creditors. The shortfall could be significant.

DESC and Santee Cooper were responsible for amounts owed to Westinghouse for valid work performed by Westinghouse subcontractors on the NND Project after the Westinghouse bankruptcy filing until termination of the interim assessment agreement. In

December 2019, DESC and Santee Cooper entered into a confidential settlement agreement with W Wind Down Co LLC resolving claims relating to the interim assessment agreement.

Further, some Westinghouse subcontractors who have made claims against Westinghouse in the bankruptcy proceeding also filed against DESC and Santee Cooper in South Carolina state court for damages. Many of these claimants have also asserted construction liens against the NND Project site. DESC also intends to oppose these claims and liens. With respect to claims of Westinghouse subcontractors, DESC believes there were sufficient amounts previously funded during the interim assessment agreement period to pay such validly asserted claims. With respect to the Westinghouse subcontractor claims which relate to other periods, DESC understands that such claims will be paid pursuant to Westinghouse’s confirmed bankruptcy reorganization plan. DESC further understands that the amounts paid under the plan may satisfy such claims in full. Therefore, DESC believes that the Westinghouse subcontractors may be paid substantially (and potentially in full) by Westinghouse. While Dominion Energy cannot be assured that it will not have any exposure on account of unpaid Westinghouse subcontractor claims, which DESC is presently disputing, Dominion Energy believes it is unlikely that it will be required to make payments on account of such ~~claims.~~

~~Nuclear Matters~~

~~In March 2011, a magnitude 9.0 earthquake and subsequent tsunami caused significant damage at~~claims that would exceed the Fukushima Daiichi nuclear power station in northeast Japan. These events resulted in significant nuclear safety reviews by the NRC and industry groups such as the Institute of Nuclear Power Operations. Like other U.S. nuclear operators, Dominion Energy has gathered supporting data and participated in industry initiatives focused on the ability to respond to and mitigate the consequences of, design-basis and beyond-design-basis events at its stations.

~~In July 2011, an NRC task force provided initial recommendations based on its review~~portion of the ~~Fukushima Daiichi accident and~~Toshiba Settlement allocated for such balances within the SCANA Merger Approval Order recorded in October 2011 the NRC staff prioritized these recommendations into Tiers 1, 2 and 3. Tier 1 recommendations consisted of actions which the NRC staff determined should be started without unnecessary delay. Tier 2 and 3 items consisted of items which could not be initiated in the near term because of resource restraints, the need for further technical assessment, or were dependentregulatory liabilities on activities related to the higher priority Tier 1 issues. In December 2011, the NRC Commissioners approved the agency staff’s prioritization and recommendations, and that same month an appropriations act directed the NRC to require reevaluation of external hazards (not limited to seismic and flooding hazards) as soon as possible.

Based on the prioritized recommendations, in March 2012, the NRC issued orders and information requests requiring specific reviews and actions to all operating reactor licensees, construction permit holders and combined license holders based on the lessons learned from the Fukushima Daiichi event. The orders applicable to Dominion Energy requiring implementation of safety enhancements related to mitigation strategies for responding to extreme natural events resulting in the loss of power at plants, and enhancing spent fuel pool instrumentation have been implemented. The information requests issued by the NRC requested each reactor licensee to reevaluate the seismic and external flooding hazards at their facility using ~~present-day~~ methods and information, conduct walkdowns of their facility to ensure protection against these hazards in their current design basis, and to reevaluate their emergency communications systems and staffing levels. The walkdowns of each unit have been completed, audited by the NRC and found to be adequate. Reevaluation of the emergency communications systems and staffing levels was completed as part of the effort to comply with the orders. Reevaluation of the seismic hazards is complete and final with NRC acceptance received for all Dominion Energy facilities. Reevaluation of the external flooding hazards is complete for all Dominion Energy facilities. The NRC approved the external flooding hazards for Surry in May 2020. NRC acceptance of the external flooding hazards reevaluations for Millstone has not yet been received, although the NRC is expected to accept the analysis in 2020. Dominion Energy and Virginia Power do not currently expect that compliance with the NRC’s information requests will materially impact their financial position, results of operations or cash flows during the implementation period. The NRC staff has resolved the Tier 2 and Tier 3 recommendations and no additional future actions on the part of Dominion Energy are anticipated with respect to these recommendations. Therefore, Dominion Energy and Virginia Power do not expect material financial impacts related to compliance with Tier 2 and Tier 3 recommendations.Energy’s Consolidated Balance Sheets.

Nuclear Operations

Nuclear Insurance

~~During~~Other than the ~~second quarter of 2020,~~items discussed below, there have been no significant changes regarding the Companies’ nuclear insurance as described in Note 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2020.

In March 2021, the total liability protection per nuclear incident available to all participants in the Secondary Financial Protection Program decreased from ~~$13.9~~$13.8 billion to ~~$13.8~~$13.7 billion. ~~This decrease does~~In June 2021, the total liability protection per nuclear incident available to all participants in the Secondary Financial Protection Program decreased from $13.7 billion to $13.5 billion. These decreases do not impact Dominion Energy’s responsibility per active unit under the Price-Anderson Amendments Act of 1988.

Effective June 2021, Dominion Energy reduced the levels of nuclear property insurance coverage for each of the reactor sites at Millstone, North Anna and Surry from $1.70 billion to the NRC minimum requirement of $1.06 billion. As a result of this reduction in nuclear property insurance coverage, Dominion Energy and Virginia Power’s maximum retrospective premium assessment for the current annual policy period was reduced to $76 million and $35 million, respectively.

Spent Nuclear Fuel

As discussed in Note 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019, Dominion Energy and Virginia Power~~2020, the Companies entered into contracts with the DOE for the disposal of spent nuclear fuel under provisions of the Nuclear Waste Policy Act of 1982.

In June 2018, a lawsuit for Kewaunee was filed in the U.S. Court of Federal Claims for recovery of spent nuclear fuel storage costs incurred after 2013. In March 2019, Dominion Energy amended its filing for recovery of spent nuclear fuel storage to include costs incurred for the year ended December 31, 2018. This matter is pending.

Guarantees, Surety Bonds and Letters of Credit

Upon the closing of the GT&S Transaction, Dominion Energy retained its 4 guarantees related to Cove Point, an equity method investment, in support of terminal services, transportation and construction. NaN of the Cove Point guarantees have a cumulative maximum exposure of $1.9 billion while the other 2 guarantees have 0 maximum limit. No amounts related to these guarantees have been recorded.

~~Dominion Energy’s guarantee agreement to support a portion of Atlantic Coast Pipeline’s obligation under a revolving credit facility is described in Note 10.~~ In addition, at June 30, ~~2020,~~2021, Dominion Energy had issued an additional ~~$27~~$25 million of guarantees, primarily to support ~~other equity method investees.~~third parties. No amounts related to ~~the other~~these guarantees have been recorded.

Dominion Energy also 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 June 30, ~~2020,~~2021, Dominion Energy had issued the following subsidiary guarantees:

Maximum
Exposure

(millions)

Commodity transactions⁽¹⁾

$
2,215

Nuclear obligations⁽²⁾

224

Cove Point⁽³⁾

1,900

Solar⁽⁴⁾

449

Other⁽⁵⁾

460

Total⁽⁶⁾

$
5,248

	Maximum Exposure
(millions)
Commodity transactions⁽¹⁾	$	1,859
Nuclear obligations⁽²⁾		202
Solar⁽³⁾		463
Other⁽⁴⁾		1,257
Total⁽⁵⁾	$	3,781

(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)	Guarantees related to Cove Point, in support of terminal services, transportation and construction. Cove Point has two guarantees that have no maximum limit and, therefore, are not included in this amount.

~~(4)~~

Includes guarantees to facilitate the development of solar projects. Also includes guarantees entered into by DGI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.

~~(5)~~(4)

Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations, construction projects and insurance programs. Also includes guarantees entered into by Dominion Energy RNG Holdings II, Inc. on behalf of a subsidiary to facilitate construction of renewable natural gas facilities. Due to the uncertainty of workers’ compensation claims, the parental guarantee has no stated limit.

~~(6)~~(5)

Excludes Dominion Energy's guarantees for the new corporate office ~~properties~~property and an offshore wind installation vessel discussed in Note 15 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019 and in Note 14 in this report.~~2020.

Additionally, at June 30, ~~2020,~~2021, Dominion Energy had purchased ~~$177~~$168 million of surety bonds, including ~~$89~~$94 million at Virginia Power, ~~and $27 million at Dominion Energy Gas,~~ and authorized the issuance of letters of credit by financial institutions of ~~$103~~$99 million 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 18. 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, ~~2019.~~2020.

At June 30, ~~2020,~~2021, Dominion Energy’s ~~gross~~ credit exposure totaled $123 million, primarily related to price risk management activities. Of this amount, investment grade counterparties, including those internally rated, represented 79%. NaN single counterparty, whether investment grade or non-investment grade, exceeded $38 million of exposure. At June 30, 2021, Virginia Power’s exposure related to ~~energy marketing and price risk management activities~~wholesale customers totaled ~~$215~~$7 million. Of this amount, investment grade counterparties, including those internally rated, represented ~~95%~~60%. NaN single counterparty, whether investment grade or non-investment grade, exceeded ~~$53~~$2 million of exposure. At June 30, 2020, Virginia Power’s exposure related to wholesale customers totaled $59 million. Of this amount, investment grade counterparties, including those internally rated, represented 100%. NaN single counterparty, whether investment grade or non-investment grade, exceeded $53 million of exposure. At June 30, 2020, Dominion Energy Gas’ exposure primarily related to wholesale customers totaled $27 million. Of this

~~amount, investment grade counterparties, including those internally rated, represented 88%. NaN single counterparty, whether investment grade or non-investment grade, exceeded $3 million of exposure.~~

For the three and six months ended June 30, 2020, the Export Customers comprised approximately 36% and 34%, respectively, of Dominion Energy Gas’ total operating revenue, with Dominion Energy Gas’ largest customer representing approximately 19% and 18%, respectively, of such amounts during the periods. For the three and six months ended June 2019, the Export Customers comprised approximately 34% and 33%, respectively, of Dominion Energy Gas’ total operating revenue, with Dominion Energy Gas’ largest customer representing approximately 18% and 17%, respectively, of such amounts during the periods.

Credit-Related Contingent Provisions

~~The majority~~Certain of Dominion Energy’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion Energy 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 as of June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, Dominion Energy would have been required to post ~~$13~~$35 million and ~~$10~~$14 million, respectively, of additional collateral to its counterparties. 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 had posted $4$20 million and $1 million of collateral at June 30, 2021 and December 31, 2020, respectively, related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with ~~cash and had posted 0 collateral at December 31, 2019.~~cash. 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 was ~~$17~~$55 million and ~~$10~~$15 million at June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively, which does not include the impact of any offsetting asset positions.

If the credit-related contingent features underlying these instruments that are in a liability position and not fully collateralized with cash were fully triggered, ~~as of~~Virginia Power would 0t have been required to post any additional collateral to its counterparties at June 30, ~~2020~~2021 and ~~December 31, 2019, Virginia Power~~ would have been required to post an additional $2 million ~~and $8 million, respectively,~~ of collateral to its ~~counterparties.~~

~~Credit-related contingent provisions for Dominion Energy Gas were not material as of June 30, 2020 and~~counterparties at December 31, ~~2019.~~ 2020.

See Note 9 for further information about derivative instruments.

Note 19. Related-Party Transactions

Virginia Power ~~and Dominion Energy Gas engage~~engages in related-party transactions primarily with other Dominion Energy subsidiaries (affiliates). Virginia ~~Power and Dominion Energy Gas’~~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 ~~and Dominion Energy Gas are~~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. Dominion Energy’s transactions with equity method investments are described in Note 10. A discussion of significant related-party transactions follows.

Virginia Power

Transactions with Affiliates

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 June 30, 2021, Virginia Power’s derivative assets and liabilities with affiliates were $26 million and $1 million, respectively. At December 31, 2020, Virginia Power’s derivative assets and liabilities with affiliates were $3 million and ~~$19 million, respectively. At December 31, 2019, Virginia Power’s derivative assets and liabilities with affiliates were $3 million and $53~~$22 million, respectively. See Note 9 for more 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, ~~2019.~~2020. At June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, 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 ~~$838~~$479 million and ~~$782~~$436 million, respectively. At June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, 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 ~~$318~~$392 million and ~~$287~~$354 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 underlying the allocation of general corporate overhead expenses are reasonable.

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

	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019		2021		2020		2021		2020
(millions)
Commodity purchases from affiliates	$	104	$	119	$	315	$	391	$	126	$	104	$	307	$	315
Services provided by affiliates⁽¹⁾		114		161		235		280		122		114		247		235
Services provided to affiliates		4		8		9		14		4		4		9		9

(1)	Includes capitalized expenditures of $44 million and $34 million for ~~both~~ the three months ended June 30, 2021 and 2020, respectively, and ~~2019,~~$82 million and $68 ~~million and $67~~ million for the six months ended June 30, ~~2020~~2021 and ~~2019,~~2020, respectively.

Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were ~~$340~~$348 million and $380 million in short-term demand note borrowings from Dominion Energy as of June 30, ~~2020~~2021 and ~~$107 million in short-term demand note borrowings from Dominion Energy as of~~ December 31, ~~2019.~~2020, respectively. Virginia Power had 0 outstanding borrowings, net of repayments, under the Dominion Energy money pool for its nonregulated subsidiaries as of June 30, ~~2020~~2021 and December 31, ~~2019.~~2020. Interest charges related to Virginia Power’s borrowings from Dominion Energy were immaterial for the three and six months ended June 30, ~~2020~~2021 and ~~2019.~~2020.

There were 0 issuances of Virginia Power’s common stock to Dominion Energy for the three and six months ended June 30, ~~2020~~2021 and ~~2019.~~2020.

~~Dominion Energy Gas~~

~~Transactions with Related Parties~~

Dominion Energy Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Energy Gas provides transportation and storage services to affiliates. Dominion Energy Gas also enters into certain other contracts with affiliates and related parties, including construction services, which are presented separately from contracts involving commodities or services. As of June 30, 2020 and December 31, 2019, Dominion Energy Gas did 0t have any commodity derivative assets or liabilities with affiliates. See Notes 7 and 9 for more information. See Note 10 for information regarding transactions with Atlantic Coast Pipeline. See Note 3 for information regarding the Dominion Energy Gas Restructuring, an affiliated transaction.

Dominion Energy Gas participates in certain Dominion Energy benefit plans as described in Note 21 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019. At June 30, 2020 and December 31, 2019, amounts due from Dominion Energy associated with the Dominion Energy Pension Plan included in other deferred charges and other assets in the Consolidated Balance Sheets were $334 million and $326 million, respectively. At June 30, 2020 and December 31, 2019, Dominion Energy Gas’ amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan included in other deferred charges and other assets in the Consolidated Balance Sheets were $20 million and $17 million, respectively.

DES, DECGS, DEQPS and other affiliates provide accounting, legal, finance, marketing and certain administrative and technical services to Dominion Energy Gas. Dominion Energy Gas provides certain services to related parties, including technical services.

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

~~Presented below are Dominion Energy Gas’ significant transactions with DES, DECGS, DEQPS and other affiliates and related parties:~~

Three Months Ended June 30,

Six Months Ended June 30,

2020

2019

2020

2019

(millions)

Sales of natural gas and transportation and storage services

$
60

$
60

$
128

$
127

Purchases of natural gas and transportation storage services

3

—

6

—

Services provided by related parties⁽¹⁾

37

59

80

104

Services provided to related parties⁽²⁾

29

45

61

90

~~(1)~~

Includes capitalized expenditures of $4 million and $5 million for the three months ended June 30, 2020 and 2019, respectively, and $7 million and $11 million for the six months ended June 30, 2020 and 2019, respectively.

~~(2)~~

~~Amounts primarily attributable to Atlantic Coast Pipeline, a related-party VIE.~~

~~The following table presents affiliated and related party balances reflected in Dominion Energy Gas’ Consolidated Balance Sheets:~~

June 30, 2020

December 31, 2019

(millions)

Other receivables⁽¹⁾

$
7

$
7

Imbalances receivable from affiliates

3

8

Imbalances payable to affiliates⁽²⁾

2

1

Other deferred charges and other assets

10

12

~~(1)~~

~~Represents amounts due from Atlantic Coast Pipeline, a related-party VIE.~~

~~(2)~~

~~Amounts are presented in other current liabilities in Dominion Energy Gas’ Consolidated Balance Sheets.~~

Affiliated receivables at June 30, 2020 and December 31, 2019 included $18 million and $22 million, respectively, of accrued unbilled revenue. This revenue is based on estimated amounts of services provided but not yet billed to various affiliates.

~~Dominion Energy Gas’ affiliated borrowings and investments are discussed in Note 25 to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019.~~

Dominion Energy Gas had $263 million in affiliated notes receivable under the Dominion Energy money pool as of June 30, 2020 and 0 outstanding receivables as of December 31, 2019. Interest income related to the affiliated notes receivable was less than $1 million and $2 million for the three and six months ended June 30, 2020, respectively.

Interest income on affiliated notes receivable from East Ohio and DGP for borrowings under intercompany revolving credit agreements with Dominion Energy Gas was $3 million and $8 million for the three and six months ended June 30, 2019, respectively.

~~Interest income earned on DMLPHCII’s promissory note to Dominion Energy was immaterial for both the three and six months ended June 30, 2020 and 2019.~~

~~Interest income related to Dominion Energy’s promissory note borrowings with Cove Point was $27 million and $54 million for the three and six months ended June 30, 2019, respectively.~~

Dominion Energy Gas’ affiliated notes receivable from Dominion Energy totaled $2.3 billion and $1.8 billion at June 30, 2020 and December 31, 2019, respectively. Interest income on these promissory notes was $12 million and $23 million for the three and six months ended June 30, 2020, respectively.

At December 31, 2019, Dominion Energy Gas’ affiliated notes receivable from East Ohio totaled $1.7 billion. In June 2020, East Ohio repaid the remaining principal balance outstanding. Interest income on these promissory notes were $15 million and $33 million for the three and six months ended June 30, 2020, respectively.

Dominion Energy Gas’ borrowings under the intercompany revolving credit agreement with Dominion Energy totaled $314 million and $251 million as of June 30, 2020 and December 31, 2019, respectively. Interest charges related to Dominion Energy Gas’ total borrowings from Dominion Energy were less than $1 million and $2 million for the three months and six months ended June 30, 2020, respectively, and were less than $1 million and $1 million for the three and six months ended June 30, 2019, respectively.

Interest charges related to DCP’s total borrowings from Dominion Energy under an intercompany revolving credit agreement totaled $29 million and $58 million for the three and six months ended June 30, 2019, respectively.

DCP had borrowings of $9 million with DES as of December 31, 2019. No amounts were outstanding as of June 30, 2020. Interest related to DCP’s total borrowings from DES were less than $1 million for the three and six months ended June 30, 2020 and were less than $1 million and $2 million for the three and six months ended June 2019, respectively.

In the first quarter of 2019, Dominion Energy Midstream borrowed $395 million from Dominion Energy under a $400 million promissory note with Dominion Energy that was scheduled to mature in 2022. Interest charges of $3 million and $6 million were incurred for the three and six months ended June 30, 2019, respectively.

For the six months ended June 30, 2020 and 2019, Dominion Energy Gas, including entities acquired in the Dominion Energy Gas Restructuring, distributed $1.7 billion and $323 million to Dominion Energy, respectively.

Note 20. Employee Benefit Plans

~~Dominion Energy~~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, except for $4 million and $9 million for the three and six months ended June 30, 2020, respectively, presented in discontinued operations. The non-service cost components of net periodic benefit (credit) cost are reflected in other ~~operations and maintenance expense and other~~ income ~~respectively,~~ in ~~the~~Dominion Energy’s Consolidated Statements of Income. The components of Dominion Energy’s provision for net periodic benefit cost (credit) are as follows:

	Pension Benefits						Other Postretirement Benefits						Pension Benefits						Other Postretirement Benefits
	2020			2019			2020			2019			2021			2020			2021			2020
(millions)
Three Months Ended June 30,
Service cost	$	43		$	40		$	7		$	6		$	42		$	43		$	6		$	7
Interest cost		90			98			15			17			79			90			12			15
Expected return on plan assets		(192	)		(176	)		(39	)		(35	)		(208	)		(192	)		(43	)		(39	)
Amortization of prior service cost (credit)		1			1			(13	)		(13	)		—			1			(11	)		(13	)
Amortization of net actuarial loss		48			43			2			3			49			48			1			2
Settlement and curtailment⁽¹⁾		2			71			—			42
Net periodic benefit cost (credit)	$	(8	)	$	77		$	(28	)	$	20
Settlements ⁽¹⁾														7			2			—			—
Net periodic benefit credit													$	(31	)	$	(8	)	$	(35	)	$	(28	)
Six Months Ended June 30,
Service cost	$	86		$	80		$	14		$	13		$	84		$	86		$	12		$	14
Interest cost		181			199			30			34			158			181			24			30
Expected return on plan assets		(385	)		(353	)		(78	)		(68	)		(416	)		(385	)		(87	)		(78	)
Amortization of prior service cost (credit)		1			1			(25	)		(26	)		—			1			(21	)		(25	)
Amortization of net actuarial loss		97			82			3			7			97			97			2			3
Settlement and curtailment⁽¹⁾		2			73			—			42
Net periodic benefit cost (credit)	$	(18	)	$	82		$	(56	)	$	2
Settlements ⁽¹⁾														5			2			—			—
Net periodic benefit credit													$	(72	)	$	(18	)	$	(70	)	$	(56	)

~~(1) 2019 amounts relate primarily to a voluntary retirement program.~~

~~Voluntary Retirement Program~~

In March 2019, the Companies announced a voluntary retirement program to employees that meet certain age and service requirements. In the second quarter of 2019, upon the determinations made concerning the number of employees that elected to participate in the program, Dominion Energy recorded a charge of $423 million ($316 million after-tax) included within other operations and maintenance expense ($288 million), other taxes ($23 million) and other income ($112 million), Virginia Power recorded a charge of $194 million ($144 million after-tax) included within other operations and maintenance expense ($186 million) and other taxes ($8 million) and Dominion Energy Gas recorded a charge of $74 million ($58 million after-tax) included within other operations and maintenance expense ($39 million), other taxes ($2 million), other income ($1 million) and discontinued operations ($32 million) in their respective Consolidated Statements of Income. See Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019 for more information.

(1)	2021 amounts relate primarily to the Dominion Energy executive nonqualified pension plan.

Employer Contributions

During the three and six months ended June 30, ~~2020,~~2021, Dominion Energy made 0 contributions to its qualified defined benefit pension plans or other postretirement benefit plans. Dominion Energy does 0t expect to make any contributions ~~to its defined benefit pension plans and expects to contribute $12 million to other postretirement benefit plans through VEBAs, respectively, during the remainder of 2020.~~

~~Following closing of the transaction with BHE described in Note 3, Dominion Energy expects to utilize $250 million of the proceeds from the sale to contribute~~ to its qualified defined benefit pension plans ~~by the end of 2020. In addition, Dominion Energy would not expect~~or to ~~make any further contributions to~~VEBAs associated with its other postretirement plans in ~~2020.~~2021.

~~Dominion Energy Gas~~

Dominion Energy Gas participates in certain Dominion Energy benefit plans as described in Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019. See Note 19 for more information.

~~The service cost component and~~ ~~non-service~~ cost components of net periodic benefit (credit) cost are reflected in other operations and maintenance expense and other income, respectively, in the Consolidated Statements of Income. The components of Dominion Energy Gas’ provision for net periodic benefit cost (credit) for employees represented by collective bargaining units are as follows:

Pension Benefits

Other Postretirement Benefits

2020

2019

2020

2019

(millions)

Three Months Ended June 30,

Service cost

$
2

$
4

$
—

$
1

Interest cost

2

8

1

2

Expected return on plan assets

(14
)

(39
)

(5
)

(7
)
Amortization of prior service credit

—

—

(1
)

(1
)
Amortization of net actuarial loss

2

5

1

1

Curtailment⁽¹⁾

—

1

—

1

Net periodic benefit credit

$
(8
)

$
(21
)

$
(4
)

$
(3
)
Six Months Ended June 30,

Service cost

$
3

$
8

$
1

$
2

Interest cost

5

16

2

5

Expected return on plan assets

(28
)

(78
)

(10
)

(14
)
Amortization of prior service credit

—

—

(2
)

(2
)
Amortization of net actuarial loss

4

10

1

2

Curtailment⁽¹⁾

—

1

—

1

Net periodic benefit credit

$
(16
)

$
(43
)

$
(8
)

$
(6
)

~~(1) 2019 amounts relate to a voluntary retirement program.~~

~~Employer Contributions~~

During the six months ended June 30, 2020, Dominion Energy Gas made 0 contributions to its qualified defined benefit pension plan or other postretirement benefit plans. Dominion Energy Gas does 0t expect to make contributions to its qualified defined benefit pension plan and expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs during the remainder of 2020.

Note 21. 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~~ ~~Gas~~
Dominion Energy Virginia	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
	Regulated electric generation fleet⁽¹⁾	X	X
~~Gas Transmission & Storage~~	~~Regulated gas transmission and storage~~⁽²⁾	X		X
	~~LNG terminalling and storage~~	X		X
	~~Nonregulated retail energy marketing~~	X
Gas Distribution	Regulated gas distribution and storage⁽³⁾⁽²⁾	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 ~~Generation~~Assets	~~Merchant~~Nonregulated electric generation fleet	X
	Noncontrolling interest in Cove Point	X

(1)	Includes Virginia Power’s nonjurisdictional generation operations.

(2)	Includes ~~gathering and processing activities.~~

~~(3)~~

~~Includes~~renewable natural gas operations as well as Wexpro’s gas development and production 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 nonregulated retail energy marketing operations, including Dominion Energy’s noncontrolling interest in Wrangler. 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. As~~resources as well as the net impact of the gas transmission and storage operations presented in discontinued operations, which are discussed in Note 1 in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019, in December 2019, Dominion Energy realigned its segments which resulted in the formation of five primary operating segments. The information for3.

In the six months ended June 30, ~~2019 presented herein has been recast~~2021, Dominion Energy reported after-tax net expenses of $358 million in the Corporate and Other segment, including $228 million of after-tax net expenses for specific items with $314 million of after-tax net expenses attributable to ~~reflect the current segment presentation.~~

its operating segments. In the six months ended June 30, 2020, Dominion Energy reported after-tax net expenses of ~~$3.1~~$3.0 billion ~~for specific items~~ in the Corporate and Other segment, ~~with~~including $2.9 billion of after-tax net expenses for specific items with $780 million of after-tax net expenses attributable to its operating segments. ~~In the six months ended June 30, 2019, Dominion Energy reported after-tax~~

The net expenses ~~of $2.1 billion~~ for specific items ~~in the Corporate and Other segment, with $1.8 billion of net expenses~~ attributable to ~~its~~Dominion Energy’s operating ~~segments.~~segments in 2021 primarily related to the impact of the following items:

•	$266 million ($199 million after-tax) of charges associated with the settlement of the South Carolina electric base rate case, attributable to Dominion Energy South Carolina;

•	A $169 million ($127 million after-tax) loss related to economic hedging activities, attributable to Contracted Assets;

•	A $151 million ($112 million after-tax) loss from an unbilled revenue reduction at Virginia Power, attributable to Dominion Energy Virginia;

•	A $77 million ($57 million after-tax) charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to Virginia’s 2021 budget process, attributable to Dominion Energy Virginia;

•	A $70 million ($53 million after-tax) charge associated with litigation acquired in the SCANA Combination, attributable to Dominion Energy South Carolina;

•	A $68 million ($50 million after-tax) charge associated with storm damage and service restoration in Virginia Power’s service territory, attributable to Dominion Energy Virginia; and

•	A $44 million ($35 million after-tax) charge related to a revision in estimated recovery of spent nuclear fuel costs associated with the decommissioning of Kewaunee, attributable to Contracted Assets; partially offset by

•	A $328 million ($256 million after-tax) gain related to investments in nuclear decommissioning trust funds, attributable to:

•

Contracted Assets ($226 million after-tax) and;

•

Dominion Energy Virginia ($30 million after-tax); and

•	A $130 million ($97 million after-tax) benefit for a change in the CCRO reserve associated with the 2021 Triennial Review, attributable to Dominion Energy Virginia.

The net expense for specific items attributable to Dominion Energy’s operating segments in 2020 primarily related to the impact of the following items:

•	$2.8 billion ($2.2 billion after-tax) of charges associated with the cancellation of the Atlantic Coast Pipeline Project and the related portions of the Supply Header Project, attributable to Gas Transmission & Storage;

•	A $751 million ($564 million after-tax) charge primarily related to the planned early retirement of certain Virginia Power electric generation facilities, attributable to Dominion Energy Virginia; and

•	A $145 million ($115 million after-tax) loss related to investments in nuclear decommissioning trust funds, attributable to:

•

Contracted ~~Generation~~Assets ($100 million after-tax) and;

•

Dominion Energy Virginia ($15 million after-tax).

In September 2020, Dominion Energy updated its segments. The ~~net expense for specific items attributable~~historical information presented herein has been recast to ~~Dominion Energy’s operating segments in 2019 primarily related to~~reflect the ~~impact of the following items:~~

•	~~A $1.0 billion ($756~~ ~~million after-tax) charge for refunds of amounts previously collected from retail electric customers of DESC for the NND Project, attributable to Dominion Energy South Carolina;~~

•	$446 million ($339 million after-tax) of merger and integration-related costs associated with the SCANA Combination, including a $425 million ($317 million after-tax) charge related to a voluntary retirement program, attributable to:

•

~~Dominion Energy Virginia ($145 million after-tax);~~

•

~~Gas Transmission & Storage ($39 million after-tax);~~

•

~~Gas Distribution ($53 million after-tax);~~

•

~~Dominion Energy South Carolina ($64 million after-tax) and;~~

•

~~Contracted Generation ($38 million after-tax).~~

•	~~A $369 million ($275 million after-tax) charge related to the early retirement of certain Virginia Power electric generation facilities, attributable to Dominion Energy Virginia;~~

•	~~$278 million ($209 million after-tax) of charges associated with litigation acquired in the SCANA Combination, attributable to Dominion Energy South Carolina;~~

•	A $198 million tax charge for $264 million of income tax-related regulatory assets acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery, attributable to Dominion Energy South Carolina;

•	~~A $160 million ($119 million after-tax) charge related to Virginia Power’s planned early retirement of certain automated meter reading infrastructure, attributable to Dominion Energy Virginia;~~

•	~~A $135 million ($100 million after-tax) charge related to Virginia Power’s contract termination with a non-utility generator, attributable to Dominion Energy Virginia; and~~

•	A $114 million ($86 million after-tax) charge for property, plant and equipment acquired in the SCANA Combination primarily for which Dominion Energy committed to forego recovery, attributable to Dominion Energy South Carolina; partially offset by

•	~~A $336 million ($251 million after-tax) net gain related to investments in nuclear decommissioning trust funds, attributable to:~~

•

~~Contracted Generation ($222 million after-tax) and;~~

•

~~Dominion Energy Virginia ($29 million after-tax); and~~

•	A $113 million ($84 million after-tax) benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019, attributable to Dominion Energy Virginia.

current segment presentation. The following table presents segment information pertaining to Dominion Energy’s operations:

	Dominion Energy Virginia			Gas Transmission & Storage		Gas Distribution		Dominion Energy South Carolina		Contracted Generation		Corporate and Other			Adjustments & Eliminations			Consolidated Total			Dominion Energy Virginia			Gas Distribution		Dominion Energy South Carolina		Contracted Assets		Corporate and Other			Adjustments & Eliminations			Consolidated Total
(millions)
Three Months Ended June 30, 2021
Total revenue from external customers																					$	1,752		$	453	$	679	$	257	$	(115	)	$	11		$	3,037
Intersegment revenue																						(5	)		2		2		17		235			(250	)		1
Total operating revenue																						1,747			455		681		274		120			(239	)		3,038
Net income from discontinued operations																						0			0		0		0		26			0			26
Net income (loss) attributable to Dominion Energy																						431			95		84		104		(429	)		0			285
Three Months Ended June 30, 2020
Total revenue from external customers	$	1,818		$	528	$	400	$	634	$	238	$	(32	)	$	(1	)	$	3,585		$	1,818		$	400	$	634	$	234	$	14		$	12		$	3,112
Intersegment revenue		(4	)		49		2		1		5		262			(315	)		—			(4	)		2		1		15		228			(248	)		(6	)
Total operating revenue		1,814			577		402		635		243		230			(316	)		3,585			1,814			402		635		249		242			(236	)		3,106
Net income (loss) from discontinued operations																						0			0		0		51		(2,052	)		0			(2,001	)
Net income (loss) attributable to Dominion Energy		437			184		87		75		21		(1,973	)		—			(1,169	)		437			87		75		72		(1,840	)		0			(1,169	)
Three Months Ended June 30, 2019
Six Months Ended June 30, 2021
Total revenue from external customers	$	1,945		$	664	$	397	$	701	$	249	$	(18	)	$	32		$	3,970		$	3,739		$	1,428	$	1,431	$	525	$	(245	)	$	28		$	6,906
Intersegment revenue		(2	)		91		3		2		4		386			(484	)		—			(7	)		3		4		38		465			(501	)		2
Total operating revenue		1,943			755		400		703		253		368			(452	)		3,970			3,732			1,431		1,435		563		220			(473	)		6,908
Net income from discontinued operations																						0			0		0		0		54			0			54
Net income (loss) attributable to Dominion Energy		393			177		66		95		13		(690	)		—			54			865			346		186		254		(358	)		0			1,293
Six Months Ended June 30, 2020
Total revenue from external customers	$	3,756		$	1,172	$	1,287	$	1,347	$	524	$	(4	)	$	(1	)	$	8,081		$	3,756		$	1,286	$	1,347	$	522	$	123		$	27		$	7,061
Intersegment revenue		(7	)		106		5		2		9		541			(656	)		—			(7	)		6		2		23		470			(511	)		(17	)
Total operating revenue		3,749			1,278		1,292		1,349		533		537			(657	)		8,081			3,749			1,292		1,349		545		593			(484	)		7,044
Net income (loss) from discontinued operations																						0			0		0		102		(1,874	)		0			(1,772	)
Net income (loss) attributable to Dominion Energy		866			405		312		169		80		(3,271	)		—			(1,439	)		866			311		169		183		(2,968	)		0			(1,439	)
Six Months Ended June 30, 2019
Total revenue from external customers	$	3,946		$	1,647	$	1,314	$	1,390	$	601	$	(1,070	)	$	—		$	7,828
Intersegment revenue		(6	)		146		7		2		7		663			(819	)		—
Total operating revenue		3,940			1,793		1,321		1,392		608		(407	)		(819	)		7,828
Net income (loss) attributable to Dominion Energy		754			399		271		166		115		(2,331	)		—			(626	)

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.~~consolidation, including amounts related to entities presented within discontinued operations.

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. As discussed in Note 1 in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019, in December 2019, Virginia Power realigned its segments which resulted in the formation of one primary operating segment. The information for the six months ended June 30, 2019 presented herein has been recast to reflect the current segment presentation.

In the six months ended June 30, ~~2020,~~2021, Virginia Power reported after-tax net expenses of ~~$654~~$73 million ~~for specific items~~ in the Corporate and Other segment, including $94 million of after-tax net expenses for specific items all of which was attributable to its operating segment. In the six months ended June 30, ~~2019,~~2020, Virginia Power reported after-tax ~~expense~~net expenses of $652 million ~~for specific items~~ in the Corporate and Other segment, ~~with $607~~including $654 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 2021 primarily related to the impact of the following items:

•	A $151 million ($112 million after-tax) loss from an unbilled revenue reduction;

•	A $77 million ($57 million after-tax) charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to Virginia’s 2021 budget process; and

•	A $68 million ($50 million after-tax) charge associated with storm damage and service restoration in its service territory; partially offset by

•	A $130 million ($97 million after-tax) benefit for a change in the CCRO reserve associated with the 2021 Triennial Review.

The net expense for specific items attributable to Virginia Power’s operating segment in 2020 primarily related to a $751 million ($559 million after-tax) charge related to the planned early retirement of certain Virginia Power electric generation facilities.

~~The net expenses for specific items in 2019 primarily related to the impact of the following items:~~

•	~~A $369 million ($275 million after-tax) charge related to the early retirement of certain electric generation facilities;~~

•	~~A $192 million ($143 million after-tax) charge related to a voluntary retirement program;~~

•	~~A $160 million ($119 million after-tax) charge related to the planned early retirement of certain automated meter reading infrastructure;~~

•	~~A $135 million ($100 million after-tax) charge related to a contract termination with a non-utility generator; and~~

•	~~A $62 million ($46 million after-tax) charge related the abandonment of a project at an electric generating facility; partially offset by~~

•	~~A $113 million ($84 million after-tax) benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019.~~

The following table presents segment information pertaining to Virginia Power’s operations:

Dominion
Energy
Virginia

Corporate
and Other

Consolidated
Total

(millions)

Three Months Ended June 30, 2020

Operating revenue

$
1,805

$
—

$
1,805

Net income

435

55

490

Three Months Ended June 30, 2019

Operating revenue

$
1,938

$
—

$
1,938

Net income (loss)

393

(293
)

100

Six Months Ended June 30, 2020

Operating revenue

$
3,735

$
—

$
3,735

Net income (loss)

862

(652
)

210

Six Months Ended June 30, 2019

Operating revenue

$
3,932

$
(29
)

$
3,903

Net income (loss)

751

(631
)

120

~~Dominion Energy Gas~~

~~The Corporate and Other Segment of Dominion Energy Gas~~ primarily includes specific items attributable to Dominion Energy Gas’ operating segment that are not included in profit measures evaluated by executive management in assessing the segment’s performance or in allocating resources and the effect of certain items recorded at Dominion Energy Gas as a result of Dominion Energy’s basis in the net assets contributed. In addition, Corporate and Other includes the net impact of discontinued operations, which are discussed in Note 3. As discussed in Note 1 in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019, in December 2019, Dominion Energy Gas realigned its segments which resulted in the formation of one primary operating segment. The information for six months ended June 30, 2019 presented herein has been recast to reflect the current segment presentation.

In the six months ended June 30, 2020, Dominion Energy Gas reported after-tax net expenses of $365 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segment. In the six months ended June 30, 2019, Dominion Energy Gas reported after-tax net expenses of $44 million for specific items in the Corporate and Other segment, with $43 million of net expenses attributable to its operating segment.

The net expense for specific items attributable to Dominion Energy Gas’ operating segment in 2020 primarily related to a $482 million ($359 million after-tax) charge associated with the Supply Header Project.

The net expense for specific items attributable to Dominion Energy Gas’ operating segment in 2019 primarily related to a $42 million ($31 million after-tax) charge related to a voluntary retirement program.

~~The following table presents segment information pertaining to Dominion Energy Gas’ operations:~~

Gas
Transmission
& Storage

Corporate
and Other

Consolidated
Total

(millions)

Three Months Ended June 30, 2020

Operating revenue

$
510

$
—

$
510

Net income (loss) attributable to Dominion Energy Gas

163

(361
)

(198
)
Three Months Ended June 30, 2019

Operating revenue

$
530

$
—

$
530

Net income from discontinued operations

—

26

26

Net income attributable to Dominion Energy Gas

116

3

119

Six Months Ended June 30, 2020

Operating revenue

$
1,066

$
—

$
1,066

Net income (loss) attributable to Dominion Energy Gas

337

(366
)

(29
)
Six Months Ended June 30, 2019

Operating revenue

$
1,096

$
—

$
1,096

Net income from discontinued operations

—

80

80

Net income attributable to Dominion Energy Gas

254

55

309

	Dominion Energy Virginia		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2021
Operating revenue	$	1,741	$	0		$	1,741
Net income (loss)		429		(15	)		414
Three Months Ended June 30, 2020
Operating revenue	$	1,805	$	0		$	1,805
Net income		435		55			490
Six Months Ended June 30, 2021
Operating revenue	$	3,722	$	(151	)	$	3,571
Net income (loss)		861		(73	)		788
Six Months Ended June 30, 2020
Operating revenue	$	3,735	$	0		$	3,735
Net income (loss)		862		(652	)		210

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS

OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

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

Contents of MD&A

MD&A consists of the following information:

•	Forward-Looking Statements

•	Accounting Matters – Dominion Energy

•	Dominion Energy

•

Results of Operations

•

Segment Results of Operations

•	Virginia Power

•

~~Results of Operations~~

•	~~Dominion Energy Gas~~

•

Results of Operations

•	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 “anticipate,” “estimate,” “forecast,” “expect,” “believe,” “should,” “could,” “plan,” “may,” “continue,” “target” 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:

•	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, 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 current pandemic health event resulting from COVID-19, and their collateral consequences, including extended disruption of economic activity in our markets;

•	Federal, state and local legislative and regulatory developments, including changes in or interpretations of federal and state tax laws and regulations;

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

•	Changes to regulated electric rates collected by ~~Dominion Energy and Virginia Power~~the Companies and regulated gas distribution, transportation and storage rates ~~including LNG storage,~~ collected by Dominion ~~Energy and Dominion Energy Gas;~~Energy;

•	Changes in rules for RTOs and ISOs in which ~~Dominion Energy and Virginia Power~~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 Dominion Energy ~~and Dominion Energy Gas share~~shares ownership with third parties, including risks that result from lack of sole decision making authority, disputes that may arise between Dominion Energy and ~~Dominion Energy Gas and~~ third party participants and difficulties in exiting these arrangements;

•	Changes in future levels of domestic and international natural gas production, supply or consumption;

•	~~Fluctuations~~Impacts to Dominion Energy’s noncontrolling interest in Cove Point from fluctuations in future volumes of LNG imports or exports from the U.S. and other countries worldwide or demand for, purchases of, and prices related to natural gas or LNG;

•	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;

•	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 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 pipeline and 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 and construction costs;

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

•

Additional competition in industries in which the Companies operate, including in electric markets in which Dominion Energy’s merchant 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 ~~Dominion Energy and Virginia Power’s~~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, changes in supplies of natural gas delivered to Dominion ~~Energy and Dominion Energy Gas’~~Energy’s pipeline ~~systems,~~system, 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;

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

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

•	The expected timing and likelihood of ~~completion~~completing a sale of the ~~proposed transaction with BHE,~~Q-Pipe Group and the sale of Kewaunee, including the ability to obtain the requisite regulatory approvals and the terms and conditions of such regulatory approvals;

•	Adverse outcomes in litigation matters or regulatory proceedings, including matters acquired in the SCANA Combination;

•	Counterparty credit and performance risk;

•	Fluctuations in the value of investments held in nuclear decommissioning trusts by ~~Dominion Energy and Virginia Power~~the Companies and in benefit plan trusts by Dominion ~~Energy and Dominion Energy Gas;~~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 or foreign currency exchange~~ 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 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 could cause actual results to differ 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, ~~2019 and Part II. Item 1A. Risk Factors in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020.

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

Critical Accounting Policies and Estimates

As of June 30, ~~2020,~~2021, 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, ~~2019.~~2020, other than for the addition of the item below. 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 ~~goodwill,~~estimates in long-lived ~~assets~~asset and equity method ~~investments~~investment impairment testing and employee benefit plans.

Held for sale classification

Dominion Energy recognizes the assets and liabilities of a disposal group as held for sale in the period (i) it has approved and committed to a plan to sell the disposal group, (ii) the disposal group is available for immediate sale in its present condition, (iii) an active program to locate a buyer and other actions required to sell the disposal group have been initiated, (iv) the sale of the disposal group is probable, (v) the disposal group is being actively marketed for sale at a price that is reasonable in relation to its current fair value, and (vi) it is unlikely that significant changes to the plan will be made or that the plan will be withdrawn. Dominion Energy initially measures a disposal group that is classified as held for sale at the lower of its carrying value or fair value less any costs to sell. Any loss resulting from this measurement is recognized in the period in which the held for sale criteria are met. Conversely, gains are not recognized on the sale of a disposal group until closing. Upon designation as held for sale, Dominion Energy stops recording depreciation expense and assesses the fair value of the disposal group less any costs to sell at each reporting period and until it is no longer classified as held for sale.

The determination as to whether the sale of the disposal group is probable may include significant judgments from management related to the expectation of obtaining approvals from applicable regulatory agencies such as state utility regulatory commissions, FERC or the U.S. Federal Trade Commission. This analysis is generally based on orders issued by regulatory commissions, past experience and discussions with applicable regulatory authorities and legal counsel.

In May 2021, Dominion Energy entered into an agreement to sell Kewaunee, subject to termination by either party if not completed by December 2022. The consideration as to whether the sale is probable includes judgments related to the ability to obtain the approvals, in a timely manner, of the NRC and the Wisconsin Commission. Due to the uncertainty surrounding the timing of or ability to obtain approval by the Wisconsin Commission, at June 30, 2021 Dominion Energy did not conclude that the sale is probable and, as a result, the disposal group was not classified as held for sale. Dominion Energy would have recognized a loss of approximately $725 million ($570 million after-tax) if such classification had been met. This loss primarily represents the difference between the nuclear decommissioning trust and AROs at June 30, 2021. The Wisconsin Commission requires that any excess decommissioning funds be returned to WPSC and WP&L customers following completion of all decommissioning activities. See Note 3 to the Consolidated Financial Statements for additional information.

Dominion Energy

Results of Operations

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

	2020			2019			$ Change			2021		2020			$ Change
(millions, except EPS)
Second Quarter
Net income (loss) attributable to Dominion Energy	$	(1,169	)	$	54		$	(1,223	)	$	285	$	(1,169	)	$	1,454
Diluted EPS		(1.41	)		0.05			(1.46	)		0.33		(1.52	)		1.85
Year-To-Date
Net loss attributable to Dominion Energy	$	(1,439	)	$	(626	)	$	(813	)
Net income (loss) attributable to Dominion Energy										$	1,293	$	(1,439	)	$	2,732
Diluted EPS		(1.75	)		(0.78	)		(0.97	)		1.56		(1.83	)		3.39

Overview

Second Quarter ~~2020~~2021 vs. ~~2019~~2020

Net income attributable to Dominion Energy ~~decreased $1.2~~increased $1.5 billion, primarily due to the absence of charges presented in discontinued operations associated with the cancellation of the Atlantic Coast Pipeline Project and related portions of the Supply Header Project, partially offset by ~~an increase~~charges associated with the settlement of the South Carolina electric base rate case, a decrease in net investment ~~earnings~~gains on nuclear decommissioning trust funds the absence of charges related to a voluntary retirement program, the absence of a charge for Virginia Power’s contract termination with a non-utility generator, the absence of a charge for litigation acquired in the SCANA Combination and ~~the absence of a charge for the abandonment of a project at a Virginia Power electric generating facility.~~increased unrealized losses on economic hedging activities.

Year-To-Date ~~2020~~2021 vs. ~~2019~~2020

Net ~~loss~~income attributable to Dominion Energy increased ~~$813 million,~~$2.7 billion, primarily due to the absence of charges presented in discontinued operations associated with the cancellation of the Atlantic Coast Pipeline Project and related portions of the Supply Header Project, ~~a decrease in net investment earnings on nuclear decommissioning trust funds and an increase in~~the absence of charges ~~associated with~~related to the planned early retirements of certain electric generation facilities in ~~Virginia.~~Virginia and an increase in net investment earnings on nuclear decommissioning trust funds. These increases ~~in net loss~~ were partially offset by ~~the absence of charges for refunds of amounts previously~~

collected from retail electric customers of DESC for the NND Project and for certain regulatory assets and property, plant and equipment acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery, a decrease in charges associated with ~~litigation acquired in~~ the ~~SCANA Combination,~~settlement of the ~~absence of charges for the planned early retirement of certain Virginia Power automated meter reading infrastructure and the absence of charges related to a voluntary retirement program.~~South Carolina electric base rate case.

Analysis of Consolidated Operations

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

	Second Quarter								Year-To-Date								Second Quarter									Year-To-Date
	2020			2019		$ Change			2020			2019		$ Change			2021			2020			$ Change			2021		2020			$ Change
(millions)
Operating revenue	$	3,585		$	3,970	$	(385	)	$	8,081		$	7,828	$	253		$	3,038		$	3,106		$	(68	)	$	6,908	$	7,044		$	(136	)
Electric fuel and other energy-related purchases		505			718		(213	)		1,173			1,509		(336	)		487			507			(20	)		1,037		1,164			(127	)
Purchased electric capacity		11			24		(13	)		13			63		(50	)		25			11			14			36		13			23
Purchased gas		74			227		(153	)		501			957		(456	)		121			90			31			605		524			81
Net revenue		2,995			3,001		(6	)		6,394			5,299		1,095
Other operations and maintenance		995			1,283		(288	)		2,038			2,285		(247	)		895			852			43			1,882		1,743			139
Depreciation, depletion and amortization		673			661		12			1,346			1,312		34			604			578			26			1,212		1,156			56
Other taxes		256			284		(28	)		540			576		(36	)		222			220			2			479		460			19
Impairment of assets and other charges		531			312		219			1,299			1,147		152			321			44			277			416		812			(396	)
Earnings from equity method investees																		65			2			63			145		5			140
Other income		502			53		449			50			400		(350	)		312			498			(186	)		599		41			558
Earnings (loss) from equity method investees		(2,281	)		39		(2,320	)		(2,228	)		80		(2,308	)
Interest and related charges		449			452		(3	)		939			921		18			518			398			120			571		830			(259	)
Income tax expense (benefit)		(556	)		43		(599	)		(575	)		157		(732	)		(47	)		37			(84	)		165		(13	)		178
Net income (loss) from discontinued operations including noncontrolling interests																		26			(2,001	)		2,027			54		(1,772	)		1,826
Noncontrolling interests		37			4		33			68			7		61			10			37			(27	)		10		68			(58	)

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

Second Quarter ~~2020~~2021 vs. ~~2019~~2020

~~Net~~Operating revenue ~~remained substantially consistent,~~decreased 2%, primarily reflecting:

•	A ~~$60~~$147 million decrease due to unfavorable pricing at Millstone, including the economic hedging impacts of net realized and unrealized losses on freestanding derivatives ($138 million);

•	A $25 million decrease in sales to electric utility ~~retail~~ customers ~~from a decrease in cooling degree days;~~associated with economic and other usage factors;

•	A ~~$44~~$22 million decrease from Virginia Power riders; and

•	An $18 million decrease in PJM off-system sales.

These decreases were partially offset by:

•	A $45 million increase from the absence of planned outages at Millstone;

•	A $39 million increase in the fuel cost components included in utility rates as a result of an increase in commodity costs associated with sales to gas utility customers ($27 million) and electric utility customers ($12 million);

•	A $28 million increase from gas utility capital cost riders; and

•	A $24 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days.

Electric fuel and other energy-related purchases decreased 4%, primarily due to a decrease in PJM off-system sales.

Purchased gas increased 34%, primarily due to an increase in commodity costs for gas utilities, which are offset in operating revenue and do not impact net income.

Other operations and maintenance increased 5%, primarily reflecting:

•	A $44 million charge related to a revision in estimated recovery of spent nuclear fuel costs associated with ~~usage factors impacted by COVID-19;~~the decommissioning of Kewaunee;

•	A $33 million increase in outside services;

•	A $20 million ~~decrease due to unfavorable pricing at Millstone, including the effects~~increase in costs of ~~the Millstone 2019 power purchase agreements;~~employer-provided healthcare; and

•	A $14 million ~~net unrealized loss on freestanding commodity derivatives.~~

~~These decreases were substantially offset by:~~

•	~~A $98 million~~ increase ~~from~~in storm damage and service restoration costs in Virginia ~~Power rate adjustment clauses;~~Power’s service territory; partially offset by

•	The absence of a ~~$24~~$22 million ~~loss~~charge associated with credit risk on customer accounts related to COVID-19;

•	A $18 million decrease in outage costs;

•	A $15 million decrease in merger and integration-related costs associated with the SCANA Combination; and

•	A $15 million decrease in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income.

Impairment of assets and other charges increased $277 million, primarily due to charges associated with the settlement of the South Carolina electric base rate case ($249 million), litigation acquired in the SCANA Combination ($40 million) and the write-off of nonregulated retail software development assets ($20 million), partially offset by the absence of dismantling costs associated with certain Virginia Power electric generation facilities ($30 million).

Earnings from equity method investees increased $63 million, primarily due to an increase in equity method earnings from Cove Point following closing of the GT&S Transaction.

Other income decreased 37%, primarily due to a decrease in net investment gains on nuclear decommissioning trust funds ($200 million) and charges associated with the settlement of the South Carolina electric base rate case ($18 million) partially offset by an increase in non-service components of pension and other postretirement employee benefit plan credits ($28 million).

Interest and related charges increased 30%, primarily due to unrealized losses in 2021 compared to unrealized gains in 2020 associated with freestanding derivatives ($142 million) partially offset by the absence of borrowings in response to COVID-19 in 2020 ($24 million).

Income tax expense decreased $84 million, primarily due to lower pre-tax income ($190 million) and the benefit of a state legislative change ($21 million) partially offset by reduced interim period tax allocation benefits ($140 million).

Net income from discontinued operations including noncontrolling interests increased $2.0 billion, primarily due to a decrease in charges associated with the Atlantic Coast Pipeline Project and related Supply Header Project ($2.1 billion) partially offset by the absence of operations sold in the GT&S Transaction ($81 million).

Noncontrolling interests decreased 73%, primarily due to the closing of the GT&S Transaction in November 2020.

Year-To-Date 2021 vs. 2020

Operating revenue decreased 2%, primarily reflecting:

•	A $198 million decrease due to unfavorable pricing at Millstone, including the economic hedging impacts of net realized and unrealized losses on freestanding commodity derivatives ($220 million);

•	A $151 million decrease from an unbilled revenue reduction at Virginia Power;

•	A $62 million decrease in sales to electric utility retail customers associated with economic and other usage factors;

•	A $45 million decrease as a result of the contribution of ~~SEMI~~certain nonregulated natural gas retail energy contracts to Wrangler; and

•	A ~~$16~~$35 million decrease in PJM off-system sales.

These decreases were partially offset by:

•	A $109 million increase in sales to electric utility retail customers from an increase in cooling degree days during the cooling season ($24 million) and an increase in heating degree days during the heating season ($85 million);

•	A $63 million increase from gas utility capital cost riders;

•	A $49 million increase from Virginia Power ~~electric capacity expense related~~riders;

•	A $34 million increase from the absence of planned outages at Millstone;

•

A $33 million net increase in the fuel cost component included in utility rates as a result of an increase in commodity costs associated with sales to ~~the annual PJM capacity performance market effective June 2019~~gas utility customers ($21103 million) partially offset by ~~the expiration of various contracts~~a decrease in commodity costs associated with sales to electric utility retail customers ($570 million).; and

•	A $24 million increase in sales to electric utility retail customers associated with growth.

Electric fuel and other energy-related purchases decreased 11%, primarily due to lower commodity costs for electric utilities ($70 million), which are offset in operating revenue and do not impact net income, and a decrease in PJM off-system sales ($35 million).

Purchased electric capacity increased $23 million, primarily due to an increase in expense related to the annual PJM capacity performance market effective June 2020.

Purchased gas increased 15%, primarily due to an increase in commodity costs for gas utilities, which are offset in operating revenue and do not impact net income.

Other operations and maintenance increased 8%, primarily reflecting:

•	A $62 million increase in storm damage and restoration costs in Virginia Power’s service territory;

•	A $47 million increase in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income;

•	A $44 million charge related to a revision in estimated recovery of spent nuclear fuel costs associated with the decommissioning of Kewaunee;

•	A $33 million increase in costs of employer-provided healthcare; and

•	A $32 million increase in outside services; partially offset by

•	A $23 million decrease in merger and integration-related costs associated with the SCANA Combination; and

•	The absence of a $22 million charge associated with credit risk on customer accounts related to COVID-19.

Impairment of assets and other chargesdecreased ~~22%~~49%, primarily reflecting:

•	The absence of ~~a charge related to a~~ ~~voluntary retirement program~~charges associated with the planned early retirements of certain electric generation facilities in Virginia ($~~288~~750 million);

•	A ~~$38 million~~ decrease ~~in salaries, wages and benefits; and~~

•	~~A $30 million decrease in outage costs; partially offset by~~

•	~~A $22 million increase in allowance for credit risk on customer accounts related~~ to the ~~effects of COVID-19;~~

•	~~A $16 million increase in certain Virginia Power expenditures, which are primarily recovered through state and FERC rates and do not impact net income~~CCRO reserve associated with the 2021 Triennial Review ($130 million); and

•	~~A $14 million increase in outside services and safety equipment related to the effects of COVID-19.~~

~~Depreciation, depletion and amortization~~ ~~increased 2%, primarily due to various projects being placed into service ($32 million), partially offset by the~~The absence of ~~depreciation from certain electric generation facilities that have been committed to be retired early ($16 million).~~

~~Other taxes~~ ~~decreased 10%, primarily due to the absence of a charge related to a voluntary retirement program ($23 million).~~

~~Impairment of assets and other charges~~ ~~increased 70%, primarily due to:~~

•	~~A $482 million charge associated with the probable abandonment of portions of the Supply Header Project related to the Atlantic Coast Pipeline Project; and~~

•	~~An increase in~~ dismantling costs associated with certain Virginia Power electric generation facilities ($30 million); partially offset by

•	~~The absence~~Charges associated with the settlement of ~~a $135 million charge related to Virginia Power’s contract termination with a non-utility generator;~~the South Carolina electric base rate case ($249 million);

•	~~The absence of a $100 million charge~~Charges associated with litigation acquired in the SCANA ~~Combination; and~~

•	~~The absence of a $62 million charge related to the abandonment of a project at a Virginia Power electric generating facility.~~

~~Other income~~ increased $449 million, primarily due to an increase in net investment earnings on nuclear decommissioning trust funds ($311 million) and the absence of a charge related to a voluntary retirement program ($112 million).

~~Earnings (loss) from equity method investees~~ ~~decreased $2.3 billion, primarily due to charges associated with the cancellation of the Atlantic Coast Pipeline Project.~~

~~Interest and related charges~~ ~~remained substantially consistent,~~ primarily reflecting lower interest expense from early redemptions of certain securities in 2019 and 2020 ($37 million) and a reduction in commercial paper borrowings ($13 million), substantially offset by increased borrowings in response to COVID-19 ($24 million) and increases ~~for unrealized losses associated with freestanding derivatives ($23 million).~~

~~Income tax expense~~ decreased $599 million, primarily due to a larger pre-tax loss ($683 million), partially offset by charges associated with the cancellation of the Atlantic Coast Pipeline Project and related Supply Header Project ($81 million).

~~Noncontrolling interests~~ ~~increased $33 million, primarily~~ ~~due to the sale of a 25% noncontrolling limited partnership interest in Cove Point to Brookfield in December 2019.~~

~~Year-To-Date 2020 vs. 2019~~

~~Net revenue~~ ~~increased 21%, primarily reflecting:~~

•	~~The absence of a~~ ~~$1.0 billion charge for refunds of amounts previously collected from retail electric customers of DESC for the NND Project;~~

•	~~A $226 million increase from Virginia Power rate adjustment clauses; and~~

•

~~A $48 million decrease in Virginia Power electric capacity expense related to the annual PJM capacity performance market effective June 2019~~Combination ($~~51 million) and a~~ ~~contract termination with a non-utility generator ($13 million) partially offset by the expiration of various contracts ($16 million).~~

~~These increases were partially offset by:~~

•	An $83 million decrease in sales to electric utility retail customers from a decrease in cooling degree days during the cooling season ($60 million) and a net decrease in heating degree days during the heating season ($23100 million);

•	A ~~$61 million decrease due~~charge for the forgiveness of Virginia retail electric customer accounts in arrears pursuant to ~~unfavorable pricing at Millstone, including the effects of the Millstone 2019 power purchase agreements;~~

•	~~A $46 million decrease in sales to electric utility retail customers associated with usage factors impacted by COVID-19;~~

•	~~A $22 million decrease as a result of the contribution of SEMI to Wrangler; and~~

•	~~A $20 million decrease in services performed for Atlantic Coast Pipeline.~~

~~Other operations and maintenance~~ ~~decreased 11%, primarily reflecting:~~

•	~~The absence of a charge related to a~~ ~~voluntary retirement program~~Virginia’s 2021 budget process ($~~288~~77 million);

•	A ~~decrease in merger and integration-related costs associated with the SCANA Combination~~charge for corporate office lease termination ($9671 million);

•	~~A $56 million decrease in salaries, wages and benefits;~~

•	~~A $40 million decrease in outage costs; and~~

•	~~A $20 million decrease in services performed for Atlantic Coast Pipeline; partially offset by~~

•	~~The absence of a benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019 ($113 million);~~

•	~~A $55 million increase in certain Virginia Power expenditures, which are primarily recovered through state and FERC rates and do not impact net income~~; and

•	A ~~$22 million increase in allowance~~charge for ~~credit risk on customer accounts related to~~ the ~~effects~~write-off of ~~COVID-19.~~

~~Depreciation, depletion and amortization~~ increased 3%, primarily due to various projects being placed into service ($59 million) partially offset by the absence of depreciation from certain electric generation facilities that were, or have been committed to be retired early ($25 million) and a decrease reflecting the expected approval of the nuclear plant life extensions from the NRC ($16nonregulated retail software development assets ($20 million).

~~Impairment of assets and other charges~~ ~~increased~~ ~~13%, primarily due to:~~

•	~~A $482 million charge associated with the probable abandonment of portions of the Supply Header Project related to the Atlantic Coast Pipeline Project;~~

•	~~An increase in charges associated with the planned early retirements of certain electric generation facilities in Virginia ($379 million); and~~

•	~~An increase in dismantling costs associated with certain Virginia Power electric generation facilities ($30 million); partially offset by~~

•	~~The absence of charges associated with litigation acquired in the SCANA Combination ($278 million);~~

•	~~The absence of a $160 million charge related to Virginia Power’s planned early retirement of certain automated meter reading infrastructure;~~

•	~~The absence of a $135 million charge related to Virginia Power’s contract termination with a non-utility generator;~~

•	~~A decrease in charges for~~ ~~property, plant and equipment acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery ($103 million); and~~

•	~~The absence of a $62 million charge related to the abandonment of a project at a Virginia Power electric generating facility.~~

Earnings from equity method investees increased $140 million, primarily due to an increase in equity method earnings from Cove Point following closing of the GT&S Transaction.

Other income ~~decreased 88%,~~increased $558 million, primarily ~~reflecting~~due to net investment gains in 2021 compared to net investment losses in 2020 ~~compared to net investment gains in 2019~~ on nuclear decommissioning trust funds ($~~481~~471 million) ~~and charges associated with litigation acquired in the SCANA Combination ($25 million)~~, ~~partially offset by the absence of a charge related to a voluntary retirement program ($112 million) and~~ an increase in non-service components of pension and other postretirement employee benefit plan credits ($2664 million).

~~Earnings (loss) from equity method investees~~ ~~decreased $2.3 billion, primarily due to~~, the absence of charges associated with litigation acquired in the SCANA Combination ($25 million) and an increase in AFUDC associated with rate-regulated projects ($17 million), partially offset by charges associated with the ~~cancellation~~settlement of the ~~Atlantic Coast Pipeline Project.~~South Carolina electric base rate case ($18 million).

Interest and related charges ~~increased 2%~~decreased 31%, primarily ~~related~~due to ~~increases~~ ~~for~~unrealized gains in 2021 compared to unrealized losses in 2020 associated with freestanding derivatives ($81233 million), the absence of charges associated with the early redemption of certain securities in the first quarter of 2020 ($2531 million) and ~~increased~~the absence of borrowings in response to COVID-19 in 2020 ($24 million)~~, partially offset by lower interest expense from early redemptions of certain securities in 2019 and 2020 ($94 million) and reductions in commercial paper borrowings ($17 million)~~.

Income tax expense ~~decreased $732~~increased $178 million,primarily due to higher pre-tax income ($214 million) partially offset by the benefit of a state legislative change ($21 million).

Net income from discontinued operations including noncontrolling interests increased $1.8 billion, primarily due to a ~~larger pre-tax loss ($623 million) and the~~ ~~absence of a charge for certain income tax-related regulatory assets acquired~~decrease in ~~the SCANA Combination for which Dominion Energy committed to forgo~~

~~recovery ($198 million), partially offset by~~ charges associated with ~~the cancellation of~~ the Atlantic Coast Pipeline Project and related Supply Header Project ($812.1 billion) partially offset by the absence of operations sold in the GT&S Transaction ($218 million).

Noncontrolling interests ~~increased~~ decreased 85%~~$61 million,~~ , primarily due to the ~~sale~~closing of ~~a 25% noncontrolling limited partnership interest~~the GT&S Transaction in ~~Cove Point to Brookfield in December 2019.~~November 2020.

Segment Results of Operations

Segment results include the impact of intersegment revenues and expenses, which may result in intersegment profit and loss. In ~~December 2019,~~September 2020, Dominion Energy ~~realigned~~updated its operating segments ~~which resulted in~~following the ~~formation~~July 2020 agreement to sell substantially all of ~~five primary operating segments.~~its gas transmission and storage operations to BHE. The historical information presented herein has been recast to reflect the current segment presentation. 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									Diluted EPS									Net Income (Loss) Attributable to Dominion Energy									Diluted EPS
	2020			2019			$ Change			2020			2019			$ Change			2021			2020			$ Change			2021			2020			$ Change
(millions, except EPS)
Second Quarter
Dominion Energy Virginia	$	437		$	393		$	44		$	0.52		$	0.49		$	0.03		$	431		$	437		$	(6	)	$	0.53		$	0.52		$	0.01
Gas Transmission & Storage		184			177			7			0.22			0.22			(0.00	)
Gas Distribution		87			66			21			0.10			0.08			0.02			95			87			8			0.12			0.10			0.02
Dominion Energy South Carolina		75			95			(20	)		0.09			0.12			(0.03	)		84			75			9			0.10			0.09			0.01
Contracted Generation		21			13			8			0.03			0.02			0.01
Contracted Assets																				104			72			32			0.13			0.09			0.04
Corporate and Other		(1,973	)		(690	)		(1,283	)		(2.37	)		(0.88	)		(1.49	)		(429	)		(1,840	)		1,411			(0.55	)		(2.32	)		1.77
Consolidated	$	(1,169	)	$	54		$	(1,223	)	$	(1.41	)	$	0.05		$	(1.46	)	$	285		$	(1,169	)	$	1,454		$	0.33		$	(1.52	)	$	1.85

Year-To-Date
Dominion Energy Virginia	$	866		$	754		$	112		$	1.03		$	0.95		$	0.08		$	865		$	866		$	(1	)	$	1.07		$	1.03		$	0.04
Gas Transmission & Storage		405			399			6			0.48			0.50			(0.02	)
Gas Distribution		312			271			41			0.37			0.34			0.03			346			311			35			0.43			0.37			0.06
Dominion Energy South Carolina		169			166			3			0.20			0.21			(0.01	)		186			169			17			0.23			0.20			0.03
Contracted Generation		80			115			(35	)		0.10			0.14			(0.04	)
Contracted Assets																				254			183			71			0.31			0.22			0.09
Corporate and Other		(3,271	)		(2,331	)		(940	)		(3.93	)		(2.92	)		(1.01	)		(358	)		(2,968	)		2,610			(0.48	)		(3.65	)		3.17
Consolidated	$	(1,439	)	$	(626	)	$	(813	)	$	(1.75	)	$	(0.78	)	$	(0.97	)	$	1,293		$	(1,439	)	$	2,732		$	1.56		$	(1.83	)	$	3.39

Dominion Energy Virginia

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

	Second Quarter							Year-To-Date							Second Quarter							Year-To-Date
	2020		2019		% Change			2020		2019		% Change			2021		2020		% Change			2021		2020		% Change
Electricity delivered (million MWh)		18.7		20.6		(9	)%		39.5		42.4		(7	)%		19.3		18.7		3	%		41.0		39.5		4	%
Electricity supplied (million MWh):
Utility		20.1		20.9		(4	)		42.5		42.8		(1	)		19.5		19.9		(2	)		41.4		42.2		(2	)
Non-Jurisdictional																0.3		0.2		50			0.5		0.3		67
Degree days (electric distribution and utility service area):
Cooling		438		644		(32	)		452		649		(30	)		509		438		16			520		452		15
Heating		371		150		147			1,889		2,042		(7	)		285		371		(23	)		2,174		1,889		15
Average electric distribution customer accounts (thousands)		2,656		2,622		1			2,652		2,620		1			2,693		2,656		1			2,688		2,652		1

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

	Second Quarter 2020 vs. 2019 Increase (Decrease)						Year-To-Date 2020 vs. 2019 Increase (Decrease)						Second Quarter 2021 vs. 2020 Increase (Decrease)						Year-To-Date 2021 vs. 2020 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(22	)	$	(0.03	)	$	(48	)	$	(0.06	)	$	14		$	0.02		$	65		$	0.08
Other		(15	)		(0.02	)		(11	)		(0.01	)		(28	)		(0.03	)		(40	)		(0.05	)
Rate adjustment clause equity return		32			0.04			55			0.07
Rider equity return														6			0.01			10			0.01
Electric capacity		9			0.01			33			0.04			(8	)		(0.01	)		(13	)		(0.02	)
Outages		14			0.02			22			0.02
Salaries, wages and benefits		15			0.02			26			0.03
Planned outage costs														(10	)		(0.01	)		(14	)		(0.02	)
Depreciation and amortization		9			0.01			21			0.02			(5	)		(0.01	)		(11	)		(0.01	)
Renewable energy investment tax credits		(10	)		(0.01	)		19			0.02			36			0.04			4			0.01
Other		12			0.01			(5	)		—			(11	)		(0.02	)		(2	)		—
Share dilution		—			(0.02	)		—			(0.05	)
Share accretion														—			0.02			—			0.04
Change in net income contribution	$	44		$	0.03		$	112		$	0.08		$	(6	)	$	0.01		$	(1	)	$	0.04

Gas ~~Transmission & Storage~~

~~Presented below are selected operating statistics related to Gas Transmission & Storage’s operations:~~

Second Quarter

Year-To-Date

2020

2019

% Change

2020

2019

% Change

Average retail energy marketing customer
accounts⁽¹⁾ (thousands)

400

790

(49
)%

399

792

(50
)%

~~(1)~~

~~Excludes accounts held by equity method investees.~~

~~Presented below, on an after-tax basis, are the key factors impacting Gas Transmission & Storage’s net income contribution:~~

Second Quarter
2020 vs. 2019
Increase (Decrease)

Year-To-Date
2020 vs. 2019
Increase (Decrease)

Amount

EPS

Amount

EPS

(millions, except EPS)

Noncontrolling interest

$
(24
)

$
(0.03
)

$
(44
)

$
(0.06
)
Contribution to Wrangler

6

0.01

(11
)

(0.01
)
Atlantic Coast Pipeline equity earnings

(4
)

(0.01
)

4

0.01

Salaries, wages and benefits

6

0.01

9

0.01

Interest expense, net

23

0.03

49

0.06

Other

—

—

(1
)

—

Share dilution

—

(0.01
)

—

(0.03
)
Change in net income contribution

$
7

$
0.00

$
6

$
(0.02
)

~~Gas~~ Distribution

Presented below are selected operating statistics related to Gas Distribution’s operations:

	Second Quarter							Year-To-Date							Second Quarter							Year-To-Date
	2020		2019		% Change			2020		2019		% Change			2021		2020		% Change			2021		2020		% Change
Gas distribution throughput (bcf):
Sales		24		24	—		%		104		112		(7	%)		24		24		—	%		110		104		6	%
Transportation		190		161		18			440		401		10			216		190		14			489		440		11
Heating degree days (gas distribution service area):
North Carolina		314		155		103			1,648		1,811		(9	)		281		314		(11	)		1,973		1,648		20
Ohio and West Virginia		804		526		53			3,246		3,441		(6	)		691		804		(14	)		3,449		3,246		6
Utah, Wyoming and Idaho		547		634		(14	)		2,879		3,204		(10	)		535		547		(2	)		2,933		2,879		2
Average gas distribution customer accounts (thousands):
Sales		1,885		1,846		2			1,888		1,847		2			1,926		1,885		2			1,925		1,888		2
Transportation		1,130		1,116		1			1,122		1,112		1			1,137		1,130		1			1,135		1,122		1

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

	Second Quarter 2020 vs. 2019 Increase (Decrease)				Year-To-Date 2020 vs. 2019 Increase (Decrease)						Second Quarter 2021 vs. 2020 Increase (Decrease)						Year-To-Date 2021 vs. 2020 Increase (Decrease)
	Amount		EPS		Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated gas sales:
Weather	$	3	$	—	$	(2	)	$	—		$	(1	)	$	—		$	3		$	—
Other		1		—		12			0.01			4			—			7			0.01
Salaries, wages and benefits		8		0.01		12			0.02
Rider equity return												10			0.01			21			0.03
Interest expense, net		5		0.01		11			0.01			7			0.01			16			0.02
Other		4		—		8			0.01			(12	)		(0.01	)		(12	)		(0.02	)
Share dilution		—		—		—			(0.02	)
Share accretion												—			0.01			—			0.02
Change in net income contribution	$	21	$	0.02	$	41		$	0.03		$	8		$	0.02		$	35		$	0.06

Dominion Energy South Carolina

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

	Second Quarter							Year-To-Date							Second Quarter							Year-To-Date
	2020		2019		% Change			2020		2019		% Change			2021		2020		% Change			2021		2020		% Change
Electricity delivered (million MWh)		5.2		5.8		(10	%)		10.3		10.9		(6	%)		5.4		5.2		4	%		10.7		10.3		4	%
Electricity supplied (million MWh)		5.4		6.2		(13	)		10.7		11.4		(6	)		5.7		5.4		6			11.3		10.7		6
Degree days (electric distribution service areas):
Cooling		171		268		(36	)		176		268		(34	)		171		171		—			172		176		(2	)
Heating		32		38		(16	)		610		698		(13	)		53		32		66			839		610		38
Average electric distribution customer accounts (thousands)		750		738		2			748		736		2			764		750		2			762		748		2
Gas distribution throughput (bcf):
Sales		14		15		(7	)		33		33		—			15		14		7			35		33		6
Average gas distribution customer accounts (thousands)		397		385		3			396		383		3			411		397		4			409		396		3

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

	Second Quarter 2020 vs. 2019 Increase (Decrease)						Year-To-Date 2020 vs. 2019 Increase (Decrease)						Second Quarter 2021 vs. 2020 Increase (Decrease)						Year-To-Date 2021 vs. 2020 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(23	)	$	(0.03	)	$	(14	)	$	(0.02	)	$	2		$	—		$	15		$	0.02
Other		(4	)		—			1			—			16			0.02			12			0.01
Capital cost rider														(1	)		—			(3	)		—
Regulated gas sales		2			—			6			0.01			1			—			5			0.01
Regulatory rider equity return		(4	)		—			(4	)		(0.01	)
Interest expense, net		2			—			10			0.01			4			—			6			0.01
Other		7			0.01			4			0.01			(13	)		(0.01	)		(18	)		(0.03	)
Share dilution		—			(0.01	)		—			(0.01	)
Share accretion														—			—			—			0.01
Change in net income contribution	$	(20	)	$	(0.03	)	$	3		$	(0.01	)	$	9		$	0.01		$	17		$	0.03

Contracted ~~Generation~~Assets

Presented below are selected operating statistics related to Contracted ~~Generation’s~~Asset’s operations:

Second Quarter

Year-To-Date

2020

2019

% Change

2020

2019

% Change

Electricity supplied (million MWh)

4.5

4.4

2
%

9.8

9.6

2
%

	Second Quarter							Year-To-Date
	2021		2020		% Change			2021		2020		% Change
Electricity supplied (million MWh)		5.6		4.5		24	%		10.7		9.8		9	%

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

	Second Quarter 2020 vs. 2019 Increase (Decrease)						Year-To-Date 2020 vs. 2019 Increase (Decrease)						Second Quarter 2021 vs. 2020 Increase (Decrease)						Year-To-Date 2021 vs. 2020 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Margin(1)	$	(6	)	$	(0.01	)	$	(50	)	$	(0.06	)	$	17		$	0.02		$	21		$	0.02
Planned outage costs		8			0.01			8			0.01			23			0.03			25			0.03
Renewable energy investment tax credits		7			0.01			7			0.01			(6	)		(0.01	)		23			0.03
Absence of contract associated with Fowler Ridge														6			0.01			11			0.01
Other		(1	)		—			—			—			(8	)		(0.01	)		(9	)		(0.01	)
Share dilution		—			—			—			—
Share accretion														—			—			—			0.01
Change in net income contribution	$	8		$	0.01		$	(35	)	$	(0.04	)	$	32		$	0.04		$	71		$	0.09

(1)	Includes earnings associated with a 50% noncontrolling interest in Cove Point.

Corporate and Other

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

Second Quarter

Year-To-Date

2020

2019

$ Change

2020

2019

$ Change

(millions, except EPS)

Specific items attributable to operating segments

$
(1,906
)

$
(482
)

$
(1,424
)

$
(2,937
)

$
(1,817
)

$
(1,120
)
Specific items attributable to Corporate and Other
segment

31

(83
)

114

(139
)

(301
)

162

Total specific items

(1,875
)

(565
)

(1,310
)

(3,076
)

(2,118
)

(958
)
Other corporate operations⁽¹⁾

(98
)

(125
)

27

(195
)

(213
)

18

Total net income (expense)

$
(1,973
)

$
(690
)

$
(1,283
)

$
(3,271
)

$
(2,331
)

$
(940
)
EPS impact

$
(2.37
)

$
(0.88
)

$
(1.49
)

$
(3.93
)

$
(2.92
)

$
(1.01
)

	Second Quarter									Year-To-Date
	2021			2020			$ Change			2021			2020			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	(227	)	$	224		$	(451	)	$	(314	)	$	(780	)	$	466
Specific items attributable to Corporate and Other segment		(116	)		(2,024	)		1,908			86			(2,078	)		2,164
Total specific items		(343	)		(1,800	)		1,457			(228	)		(2,858	)		2,630
Other corporate operations:
Interest expense, net		(106	)		(85	)		(21	)		(217	)		(177	)		(40	)
Other		20			45			(25	)		87			67			20
Total other corporate operations		(86	)		(40	)		(46	)		(130	)		(110	)		(20	)
Total net expense	$	(429	)	$	(1,840	)	$	1,411		$	(358	)	$	(2,968	)	$	2,610
EPS impact	$	(0.55	)	$	(2.32	)	$	1.77		$	(0.48	)	$	(3.65	)	$	3.17

~~(1)~~

~~Primarily consists of net interest expense.~~

Total Specific Items

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 21 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 June 30, 2021, this primarily included a $118 million after-tax loss for derivative mark-to-market changes, $23 million of after-tax charges for merger and integration-related costs associated with the SCANA Combination and $26 million net income of discontinued operations, primarily associated with the operations of the Q-Pipe Group. For the six months ended June 30, 2021, this primarily included a $116 million after-tax benefit for derivative mark-to-market changes, $54 million net income of discontinued operations, primarily associated with the Q-Pipe Group, a $53 million after-tax charge for corporate office lease termination associated with workplace realignment and $30 million of after-tax charges for merger and integration-related costs associated with the SCANA Combination.

For the three months ended June 30, 2020, other than the effects of required interim period provision for income taxes, this primarily included $2.1 billion net loss of discontinued operations, including the results of operations of the entities included in the GT&S Transaction and Q-Pipe Group as well as charges associated with the cancellation of the Atlantic Coast Pipeline Project and $18 million of after-tax charges for merger and integration-related costs associated with the SCANA Combination. For the six months ended June 30, 2020, this primarily included $1.9 billion net loss of discontinued operations, including the results of operations of the entities included in the GT&S Transaction and Q-Pipe Group as well as charges associated with the cancellation of the Atlantic Coast Pipeline Project, $59 million of after-tax charges for merger and integration-related costs associated with the SCANA Combination, $43 million of after-tax charges for derivative mark-to-market changes and $23 million of after-tax charges associated with the early redemption of certain debt securities.

Virginia Power

Results of Operations

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

	Second Quarter						Year-To-Date						Second Quarter							Year-To-Date
	2020		2019		$ Change		2020		2019		$ Change		2021		2020		$ Change			2021		2020		$ Change
(millions)
Net income	$	490	$	100	$	390	$	210	$	120	$	90	$	414	$	490	$	(76	)	$	788	$	210	$	578

Overview

Second Quarter ~~2020~~2021 vs. ~~2019~~2020

Net income decreased 16%, primarily due to a decrease in sales to electric utility retail customers associated with economic and other usage factors.

Year-To-Date 2021 vs. 2020

Net income increased ~~$390~~$578 million, primarily due to the absence of charges ~~related to a voluntary retirement program, a contract termination with a non-utility generator and the abandonment of a project at an electric generating facility.~~

~~Year-To-Date 2020 vs. 2019~~

Net income increased $90 million, primarily due to the absence of charges related to the planned early retirement of certain automated meter reading infrastructure, a voluntary retirement program and a contract termination with a non-utility generator. These increases were ~~partially offset by an increase in charges~~ related to the planned early retirements of certain electric generation ~~facilities and the absence of a revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019.~~facilities.

Analysis of Consolidated Operations

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

	Second Quarter								Year-To-Date								Second Quarter								Year-To-Date
	2020			2019		$ Change			2020			2019		$ Change			2021		2020			$ Change			2021			2020			$ Change
(millions)
Operating revenue	$	1,805		$	1,938	$	(133	)	$	3,735		$	3,903	$	(168	)	$	1,741	$	1,805		$	(64	)	$	3,571		$	3,735		$	(164	)
Electric fuel and other energy-related purchases		366			536		(170	)		858			1,132		(274	)		349		366			(17	)		755			858			(103	)
Purchased (excess) electric capacity		(8	)		13		(21	)		(17	)		46		(63	)		4		(8	)		12			1			(17	)		18
Net revenue		1,447			1,389		58			2,894			2,725		169
Other operations and maintenance		376			565		(189	)		794			844		(50	)		399		376			23			912			794			118
Depreciation and amortization		307			299		8			618			603		15			323		307			16			647			618			29
Other taxes		85			90		(5	)		172			175		(3	)		83		85			(2	)		176			172			4
Impairment of assets and other charges		44			197		(153	)		808			743		65
Impairment of assets and other charges (benefit)																		12		44			(32	)		(39	)		808			(847	)
Other income		52			16		36			—			53		(53	)		40		52			(12	)		72			—			72
Interest and related charges		137			135		2			263			270		(7	)		128		137			(9	)		264			263			1
Income tax expense		60			19		41			29			23		6			69		60			9			139			29			110

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

Second Quarter ~~2020~~2021 vs. ~~2019~~2020

~~Net~~Operating revenue decreased 4%, primarily reflecting:

•	A $49 million decrease in sales to electric utility retail customers associated with economic and other usage factors;

•	A $22 million decrease from riders; and

•	An $18 million decrease in PJM off-system sales; partially offset by

•	A $20 million increase in sales to retail customers, primarily due to an increase in cooling degree days.

Electric fuel and other energy-related purchases decreased 5%, primarily due to a decrease in PJM off-system sales.

Purchased electric capacity increased 4%$12 million, primarily due to an increase in expense related to the annual PJM capacity performance market effective June 2020.

Other operations and maintenance increased 6%, primarily reflecting:

•	A ~~$98~~$15 million increase ~~from rate adjustment clauses;~~in outside services;

•	A $14 million increase in storm damage and service restoration costs;

•	A $14 million increase in planned outage costs; and

•

A ~~$16~~$14 million ~~decrease~~increase in ~~electric capacity expense related to the annual PJM capacity performance market effective June 2019 ($21 million), partially offset by the expiration of various contracts ($5 million);~~salaries, wages and benefits and administrative costs; partially offset by

•	A $15 million decrease in certain expenses which are primarily recovered through state- and FERC-regulated rates and do not impact net income; and

•	The absence of a $13 million charge associated with credit risk on customer accounts related to COVID-19.

Impairment of assets and other charges decreased 73%, primarily due to the absence of charges for dismantling costs associated with certain electric generation facilities ($30 million).

Other income decreased 23%, primarily due to a decrease in net investment gains on nuclear decommissioning trust funds.

Income tax expense increased 15%, primarily due to reduced interim period tax allocation benefits ($45 million) partially offset by lower pre-tax income ($19 million) and the benefit of a state legislative change ($16 million).

Year-To-Date 2021 vs. 2020

Operating revenue decreased 4%, primarily reflecting:

•	A ~~$30~~$151 million decrease from an unbilled revenue reduction;

•	A $77 million decrease in sales to electric utility retail customers associated with economic and other usage factors;

•	A $69 million decrease in the fuel cost component included in utility rates as a result of a net decrease in commodity costs associated with sales to electric utility retail customers; and

•	A $35 million decrease in PJM off-system sales; partially offset by

•	A $88 million increase in sales to retail customers from ~~a decrease~~an increase in cooling degree ~~days;~~days during the cooling season ($20 million) and an increase in heating degree days during the heating season ($68 million);

•	A $49 million increase from riders; and

•	A $24 million ~~decrease~~increase in sales to electric utility retail customers associated with ~~usage factors impacted by COVID-19.~~growth.

Electric fuel and other energy-related purchases decreased 12%, primarily due to lower commodity costs for electric utilities ($69 million), which are offset in operating revenue and do not impact net income, and a decrease in PJM off-system sales ($35 million).

Purchased electric capacity increased $18 million, primarily due to an increase in expense related to the annual PJM capacity performance market effective June 2020.

Other operations and maintenance ~~decreased 33%~~, primarily reflecting the absence of a charge related to a voluntary retirement program ($186 million), a decrease in salaries, wages and benefits ($17 million) and a decrease in planned outage costs ($19 million). These decreases were partially offset by ~~an increase in certain expenses which are primarily recovered~~ ~~through state and FERC rates and do not impact net income ($16 million) and an increase in allowance for credit risk on customer accounts related to COVID-19 ($13 million).~~

~~Depreciation and amortization~~ increased ~~3%, primarily~~ due to various projects being placed into service ($28 million), partially offset by the absence of depreciation from certain electric generation facilities that have been committed to be retired early ($16 million) and a decrease reflecting the expected approval of the nuclear plant life extensions from the NRC ($8 million).

~~Impairment of assets and other charges~~ decreased 78%, primarily due to the absence of charges related to a contract termination with a non-utility generator ($135 million) and the abandonment of a project at an electric generating facility ($62 million), partially offset by an increase in dismantling costs associated with certain electric generation facilities ($30 million) and the write-off of the portion of a regulatory asset no longer probable of recovery as a result of the enactment of the VCEA ($16 million).

~~Other income~~ ~~increased $36 million, primarily~~ ~~reflecting an increase in net investment earnings on nuclear decommissioning trust funds.~~

~~Income tax expense~~ ~~increased $41 million, primarily due to higher pre-tax income ($80 million), partially offset by higher investment tax credits ($39 million).~~

~~Year-To-Date 2020 vs. 2019~~

~~Net revenue~~ ~~increased 6%~~15%, primarily reflecting:

•	A ~~$226~~$62 million increase ~~from rate adjustment clauses;~~in storm damage and service restoration costs;

•	A $47 million increase in certain expenses which are primarily recovered through state- and FERC-regulated rates and do not impact net income;

•	A $22 million increase in outside services;

•	A $19 million increase in planned outage costs; and

•

A ~~$48~~$13 million decrease in electric capacity expense related to the annual PJM capacity performance market effective June 2019 ($51 million) and a contract termination with a non-utility generator ($13 million) partially offset by the expiration of various contracts ($16 million); partially offset by

•	A $65 million decrease in sales to retail customers from a decrease in cooling degree days during the cooling season ($30 million) and a decrease in heating degree days during the heating season ($35 million); and

•	~~A $24 million decrease in sales to electric retail customers associated with usage factors impacted by COVID-19.~~

~~Other operations and maintenance~~ ~~decreased 6%~~, primarily reflecting the absence of a charge related to a voluntary retirement program ($186 million), a decrease in salaries, wages and benefits ($34 million) and a decrease in planned outage costs ($29 million). These decreases were partially offset by the absence of a benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019 ($113 million), an increase in certain expenses which are primarily recovered through state and FERC rates and do not impact net income ($55 million) and ~~an increase in allowance for credit risk on customer accounts related to COVID-19 ($13 million)~~.

~~Depreciation and amortization~~ ~~increased 2%, primarily~~ due to various projects being placed into service ($52 million), partially offset by the absence of depreciation from certain electric generation facilities that were, or have committed to be, retired early ($25 million) and a decrease reflecting the expected approval of the nuclear plant life extensions from the NRC ($16 million).

~~Impairment of assets and other charges~~ ~~increased 9%, primarily due to:~~

•	An ~~increase~~ ~~in charges associated with the planned early retirements of certain electric generation facilities ($379 million); and~~

•	An increase in ~~dismantling costs associated with certain electric generation facilities ($30 million);~~ salaries, wages and benefits; partially offset by

•	The absence of a $13 million charge associated with credit risk on customer accounts related to COVID-19; and

•	A $10 million reduction in bad debt expense due to the forgiveness of Virginia retail electric customer accounts in arrears pursuant to Virginia’s 2021 budget process.

Impairment of assets and other charges decreased $847 million, primarily reflecting:

•	The absence of charges associated with the planned early ~~retirement~~retirements of certain ~~automated meter reading infrastructure~~electric generation facilities ($~~160~~750 million);

•	A decrease to the CCRO reserve associated with the 2021 Triennial Review ($130 million); and

•	The absence of ~~a $135 million charge related to contract termination~~charges for dismantling costs associated with ~~a non-utility generator; and~~

•	~~The absence of a $62 million charge related to the abandonment of a project at an~~certain electric ~~generating facility.~~

~~Other income~~ ~~decreased $53 million, primarily reflecting~~ ~~net investment losses in 2020 compared to net investment gains in 2019 on nuclear decommissioning trust funds.~~

~~Income tax expense~~ ~~increased 26%, primarily due to higher pre-tax income ($25 million),~~generation facilities ($30 million); partially offset by ~~higher investment tax credits ($19 million).~~

~~Dominion Energy Gas~~

~~Results of Operations~~

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

Second Quarter

Year-To-Date

2020

2019

$ Change

2020

2019

$ Change

(millions)

Net income (loss) attributable to Dominion Energy Gas

$
(198
)

$
119

$
(317
)

$
(29
)

$
309

$
(338
)

~~Overview~~

~~Second Quarter 2020 vs. 2019~~

Net income attributable to Dominion Energy Gas decreased $317 million, primarily due to a charge associated with the probable abandonment of portions of the Supply Header Project related to the Atlantic Coast Pipeline Project and the absence of net income from discontinued operations related to the Dominion Energy Gas Restructuring, partially offset by the absence of a charge related to a voluntary retirement program and a decrease in interest and related charges from lower outstanding debt balances.

~~Year-To-Date 2020 vs. 2019~~

Net income attributable to Dominion Energy Gas decreased $338 million, primarily due to a charge associated with the probable abandonment of portions of the Supply Header Project related to the Atlantic Coast Pipeline Project and the absence of net income from discontinued operations related to the Dominion Energy Gas Restructuring, partially offset by the absence of a charge related to a voluntary retirement program and a decrease in interest and related charges from lower outstanding debt balances.

~~Analysis of Consolidated Operations~~

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

Second Quarter

Year-To-Date

2020

2019

$ Change

2020

2019

$ Change

(millions)

Operating revenue

$
510

$
530

$
(20
)

$
1,066

$
1,096

$
(30
)
Purchased gas

—

(3
)

3

8

9

(1
)
Other energy-related purchases

1

1

—

1

1

—

Net revenue

509

532

(23
)

1,057

1,086

(29
)
Other operations and maintenance

150

210

(60
)

315

386

(71
)
Depreciation and amortization

94

92

2

187

182

5

Other taxes

35

38

(3
)

77

78

(1
)
Impairment of assets and other charges

482

13

469

482

13

469

Earnings from equity method investees

8

9

(1
)

23

22

1

Other income

46

44

2

95

85

10

Interest and related charges

50

86

(36
)

108

173

(65
)
Income tax expense (benefit)

(82
)

23

(105
)

(30
)

66

(96
)
Net income from discontinued operations

—

26

(26
)

—

80

(80
)
Noncontrolling interests

32

30

2

65

66

(1
)

~~An analysis of Dominion Energy Gas’ results of operations follows:~~

~~Second Quarter 2020 vs. 2019~~

~~Net revenue~~ ~~decreased 4%, primarily reflecting:~~

•	~~A $9 million decrease in services performed for Atlantic Coast Pipeline,~~

•	A ~~$6 million decrease~~charge for the forgiveness of Virginia retail electric customer accounts in ~~services provided~~arrears pursuant to ~~affiliates; and~~

•	~~A $5 million decrease due to DETI contract changes.~~Virginia’s 2021 budget process ($77 million).

Other ~~operations~~income increased $72 million, primarily due tonet investment gains in 2021 compared to net investment losses in 2020 on nuclear decommissioning trust funds ($59 million) and ~~maintenance~~ ~~decreased 29%, primarily reflecting:~~an increase in AFUDC associated with rate-regulated projects ($13 million).

•	~~A $39 million decrease due to the absence of a charge related to a voluntary retirement program; and~~

•	~~A $9 million decrease in services performed for Atlantic Coast Pipeline.~~

~~Impairment of assets and other charges~~ Income tax expenseincreased ~~$469~~$110 million, primarily due to ~~a $482 million charge associated with the probable abandonment of portions of the Supply Header Project related to the Atlantic Coast Pipeline Project,~~higher pre-tax income ($136 million) partially offset by the ~~absence~~benefit of a ~~$13 million charge related to the abandonment of the Sweden Valley project.~~

~~Interest and related charges~~ ~~decreased 42%,primarily due to the absence of interest expense from Cove Point’s term loan borrowings~~state legislative change ($3216 million)~~, partially offset by interest expense on Dominion Energy Gas’ November 2019 senior note issuance ($8 million)~~.

~~Income tax expense~~ ~~decreased $105 million, primarily due to lower pre-tax income.~~

~~Year-To-Date 2020 vs. 2019~~

~~Net revenue~~ ~~decreased 3%, primarily reflecting:~~90

•	~~A $20 million decrease in services performed for Atlantic Coast Pipeline; and~~

•	~~An $8 million decrease in services provided to affiliates.~~

~~Other operations and maintenance~~ ~~decreased 18%, primarily reflecting:~~

•	~~A $39 million decrease due to the absence of a charge related to a voluntary retirement program; and~~

•	~~A $20 million decrease in services performed for Atlantic Coast Pipeline.~~

~~Impairment of assets and other charges~~ increased $469 million, due to a $482 million charge associated with the probable abandonment of portions of the Supply Header Project related to the Atlantic Coast Pipeline Project, partially offset by the absence of a $13 million charge related to the abandonment of the Sweden Valley project.

~~Other income~~ ~~increased 12%, primarily due to an increase in non-service components of pension and other postretirement employee benefit plan credits.~~

~~Interest and related charges~~ ~~decreased 38%,~~primarily due to the absence of interest expense from Cove Point’s term loan borrowings ($68 million), partially offset by interest expense on Dominion Energy Gas’ November 2019 senior note issuance ($15 million).

~~Income tax expense~~ ~~decreased $96 million, primarily due to lower pre-tax income.~~

Liquidity and Capital Resources

Dominion Energy depends on both internal and external sources of liquidity to provide working capital and as a bridge to long-term debt financings. Short-term cash requirements not met by cash provided by operations are generally satisfied with proceeds from short-term borrowings. Long-term cash needs are met through issuances of debt and/or equity securities.

At June 30, ~~2020,~~2021, Dominion Energy had ~~$5.7~~$3.3 billion of unused capacity under its joint revolving credit facility. ~~In addition, Dominion Energy had $675 million available under a $900 million 364-Day Revolving Credit Agreement entered into in March 2020.~~

As part of its strategic response to COVID-19, Dominion Energy undertook certain measures in March and April 2020 to buttress its liquidity position. This includes entering the $900 million 364-Day Revolving Credit Agreement, which has the potential for an additional $300 million of capacity upon certain events. In addition, Dominion Energy borrowed $1.1 billion under two 364-Day Term Loan Credit Agreements and issued $2.3 billion of senior notes. In June 2020, Dominion Energy repaid the outstanding balance of $625 million associated with one of the 364-Day Term Loan Credit Agreements. See Note 16 to the Consolidated Financial Statements for more information.

A summary of Dominion Energy’s cash flows is presented below:

	2020			2019			2021			2020
(millions)
Cash, restricted cash and equivalents at January 1	$	269		$	391		$	247		$	269
Cash flows provided by (used in):
Operating activities(1)		3,136			2,313			2,240			3,136
Investing activities(2)		(3,334	)		(1,833	)		(3,768	)		(3,334	)
Financing activities(3)		671			(311	)		1,585			671
Net increase in cash, restricted cash and equivalents		473			169			57			473
Cash, restricted cash and equivalents at June 30	$	742		$	560		$	304		$	742

(1)	Includes $108 million and $668 million related to discontinued operations for 2021 and 2020, respectively.

(2)	Includes $(980) million and $(369) million related to discontinued operations for 2021 and 2020, respectively.

(3)	Includes $(138) million related to discontinued operations for 2020 and no amounts for 2021.

Operating Cash Flows

Net cash provided by Dominion Energy’s operating activities ~~increased $823~~decreased $896 million, including a $560 million decrease from discontinued operations. Net cash provided by continuing operations decreased primarily due to ~~higher~~lower deferred fuel cost recoveries ~~lower payments for income taxes, the absence of~~and increased margin deposits, partially offset by distributions from Cove Point and a ~~contract termination payment and net changes~~decrease in ~~working capital items.~~interest payments.

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. In December 2019, Dominion Energy’s Board of Directors established an annual dividend rate for 2020 of $3.76 per share of common stock. In January 2020, Dominion Energy’s Board of Directors declared dividends payable in March 2020 of 94 cents per share of common stock, and in May 2020, Dominion Energy’s Board of Directors declared dividends payable in June 2020 of 94 cents per share of common stock. In July 2020, Dominion Energy’s Board of Directors declared dividends payable in September 2020 of 94 cents per share of common stock. Also in July 2020, Dominion Energy announced that it currently expects to make a fourth dividend payment in December 2020 of approximately 63 cents per share of common stock reflecting the expected timing of the closing of the proposed transaction with BHE. Dividends are subject to declaration by the Board of Directors.

Dominion Energy’s operations are subject to risks and uncertainties that may negatively impact the timing or amounts of operating cash flows, which are discussed in Part I. Item 1A. Risk Factors in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019 and Part II. Item 1A. Risk Factors in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020.

Credit Risk

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 as of June 30, ~~2020~~2021 for these activities. Gross credit exposure for each counterparty is calculated prior to the application of collateral and represents 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		Gross Credit Exposure		Credit Collateral		Net Credit Exposure
(millions)
Investment grade⁽¹⁾	$	88	$	—	$	88	$	78	$	—	$	78
Non-investment grade⁽²⁾		3		—		3		4		—		4
No external ratings:
Internally rated—investment grade⁽³⁾		117		—		117		22		2		20
Internally rated—non-investment grade⁽⁴⁾		7		—		7		21		—		21
Total⁽⁵⁾	$	215	$	—	$	215	$	125	$	2	$	123

(1)	Designations as investment grade are based upon minimum credit ratings assigned by Moody’s Investors Service and Standard & Poor’s. The five largest counterparty exposures, combined, for this category represented approximately ~~29%~~61% of the total net credit exposure.

(2)	The five largest counterparty exposures, combined, for this category represented ~~approximately 2%~~less than 4% of the total net credit exposure.

(3)	The five largest counterparty exposures, combined, for this category represented approximately ~~53%~~13% of the total net credit exposure.

(4)	The five largest counterparty exposures, combined, for this category represented approximately 2%6% of the total net credit exposure.

~~(5)~~

(5) Excludes the Millstone 2019 power purchase agreements.

~~Excludes the Millstone 2019 power purchase agreements.~~

Investing Cash Flows

Net cash used in Dominion Energy’s investing activities increased ~~$1.5 billion,~~$434 million, primarily due to an increase in contributions to equity method affiliates including Atlantic Coast Pipeline, partially offset by a decrease in plant construction and other property additions and the absence of ~~cash acquired in the SCANA Combination and~~ the acquisitions of Pivotal LNG, Inc. and an additional interest in Atlantic Coast Pipeline.

Financing Cash Flows and Liquidity

Dominion Energy relies on capital markets as significant sources of funding for capital requirements not satisfied by cash provided by its operations. As discussed further in Credit Ratings and Debt Covenants in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019,~~2020, the ability to borrow funds or issue securities and the return demanded by investors are affected by credit ratings. In addition, the raising of external capital is subject to certain regulatory requirements, including registration with the SEC for certain issuances.

Dominion Energy currently meets the definition of a well-known seasoned issuer under SEC rules governing the registration, ~~communications~~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. ~~In June 2020, Dominion Energy filed a SEC shelf registration statement for the sale of debt and equity securities which replaced the shelf registration statement filed by Dominion Energy in June 2017.~~

Net cash provided by Dominion Energy's financing activities ~~was $671~~increased $914 million ~~for the six months ended June 30, 2020, compared to net cash used by financing activities of $311 million for the six months ended June 30, 2019,~~ primarily due to lower common stock dividend payments and higher net issuances of short- and long-term debt to buttress liquidity as a strategic response to COVID-19 and lower repayments of long-term debt, partially offset by higher repayments of short-term debt and the absence of the issuance of the 2019 Equity Units.debt.

~~In November 2017,~~

Dominion Energy ~~filed a SEC~~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 Investment^SM. 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. ~~The balance as of~~At June 30, 2021 and December 31, 2020, ~~was $176 million. The notes are short-term debt obligations on~~ Dominion Energy’s Consolidated Balance ~~Sheets.~~Sheets include $392 million and $268 million, respectively, with respect to such notes presented within short-term debt. The proceeds ~~will be~~are used for general corporate purposes and to repay debt.

In July 2020, the Board of Directors authorized the repurchase of up to $3.0 billion of Dominion Energy’s common stock and rescinded the prior two authorizations from 2005 and 2007. The repurchase program does not include a specific timetable 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.

See Note 16 to the Consolidated Financial Statements ~~in this report~~ for further information regarding Dominion Energy’s credit facilities, liquidity and significant financing ~~transactions.~~transactions, including a $900 million Sustainability Revolving Credit Agreement entered into in June 2021 and a $1.3 billion term loan credit agreement entered into in July 2021.

Credit Ratings

Credit ratings are intended to provide banks and capital market participants with a framework for comparing the credit quality of securities and are not a recommendation to buy, sell or hold securities. In the Credit Ratings section of MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019,~~2020, there is a discussion on the use of capital markets by Dominion Energy as well as the impact of credit ratings on the accessibility and costs of using these markets. As of June 30, ~~2020,~~2021, there have been no changes in Dominion Energy’s credit ratings.

Debt Covenants

In the Debt Covenants section of MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019,~~2020, there is a discussion on the various covenants present in the enabling agreements underlying Dominion Energy’s debt. In addition, see Note 16 to the Consolidated Financial Statements in this report for a description of certain financial covenants associated with term loan and revolving credit agreements entered into in the first quarter of 2020. As of June 30, ~~2020,~~2021, there have been no material changes to debt covenants, nor any events of default under Dominion Energy’s debt covenants.

Subsidiary Dividend Restrictions

As of June 30, 2021, there have been no material changes to the subsidiary dividend restrictions disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2020.

Future Cash Payments for Contractual Obligations and Planned Capital Expenditures

As of June 30, ~~2020,~~2021, there have been no material changes outside the ordinary course of business to Dominion Energy’s contractual obligations nor any material changes to planned capital expenditures as disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019.~~2020.

Use of Off-Balance Sheet Arrangements

As of June 30, ~~2020,~~2021, there have been no material changes to the off-balance sheet arrangements disclosed in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019,~~2020, with the exception of the ~~following matter.~~

~~In December 2019, Dominion Energy signed an agreement with a lessor, as amended~~matter disclosed in ~~May 2020, to construct and lease a new corporate office property~~Use of Off-Balance Sheet Arrangements in ~~Richmond, Virginia. The lessor is providing equity and has obtained financing commitments from debt investors, totaling $465 million, to fund~~MD&A in the ~~estimated project costs. If Dominion Energy ultimately proceeds with the project through completion,~~ ~~the project is expected to be completed by September 2024. Dominion Energy has been appointed to act as the construction agent~~Companies’ Quarterly Report on Form 10-Q for the lessor, during which time Dominion Energy will request cash draws from the lessor and debt investors to fund all project costs. If the project is terminated under certain events, Dominion Energy could be required to pay up to 100% of the then funded amount.quarter ended March 31, 2021.

The lease term will commence once construction is substantially complete and the facility is able to be occupied and end in December 2027. At the end of the initial lease term, Dominion Energy can (i) extend the term of the lease for an additional five years, 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, up to 83% of project costs, for the difference between the project costs and sale proceeds. Dominion Energy is not considered the owner during construction for financial accounting purposes and, therefore, will not reflect the construction activity in its consolidated financial statements. Dominion Energy expects to recognize a right-of-use asset and a corresponding finance lease liability at the commencement of the lease term. Dominion Energy will be considered the owner of the leased property for tax purposes, and as a result, will be entitled to tax deductions for depreciation and interest expense.

Future Issues and Other Matters

The following discussion of future issues and other information includes current developments of previously disclosed matters and new issues arising during the period covered by, and subsequent to, the dates of Dominion Energy’s Consolidated Financial Statements that may impact future results of operations, financial condition and/or cash flows. This section should be read in conjunction with Item 1. Business and Future Issues and Other Matters in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019,~~2020, Future Issues and Other Mattersin MD&A in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, ~~2020~~2021 and Note 17 to the Consolidated Financial Statements in this report.

Environmental Matters

Dominion Energy is 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. See Note 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019, Note 17 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020 and Note 17 to the Consolidated Financial Statements in this report for additional information on various environmental matters.

Legal Matters

See Notes 13 and 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December ~~31, 2019, Notes 13 and 17 to the Consolidated Financial Statements and~~ ~~Item 1. Legal Proceedings~~ ~~in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March~~ 31, 2020 and Notes 13 and 17 to the Consolidated Financial Statements and Item 1. Legal Proceedings in this report for additional information on various legal matters.

Regulatory Matters

See Notes 3 and 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019, Note 13 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020 and Note 13 to the Consolidated Financial Statements in this report for additional information on various regulatory matters.

~~Atlantic Coast Pipeline and Supply Header Projects~~Coastal Virginia Offshore Wind Commercial Project

In ~~July 2020, Dominion Energy~~September 2019, Virginia Power filed applications with PJM for the Coastal Virginia Offshore Wind Commercial project to interconnect 2,640 MW of wind energy off the coast of Virginia adjacent to the Coastal Virginia Offshore Wind Pilot project. The project is expected to be placed in service by the end of 2026 with preliminary cost estimates from late 2019 of approximately $8 billion. Throughout project development, certain planning inputs and ~~Duke Energy announced~~assumptions may vary from initial and preliminary estimates. During 2021, inflationary pressure on certain raw materials including steel have been observed which may impact project costs. In addition, Virginia Power has moved into the ~~cancellation~~detailed design phase for the project’s onshore electric transmission facilities including final route selection with consideration given for resiliency and minimizing environmental impacts. Although total costs for this component cannot be more precisely estimated until a final route is selected, these design factors will likely result in an increase in costs. While certain cost inputs may increase, further evaluation of turbine design and wind resource in addition to the performance to-date of the ~~Atlantic Coast Pipeline Project. As~~Coastal Virginia Offshore Wind Pilot project, is likely to result in a ~~result, Dominion Energy recorded an abandonment for a significant portion~~revised assumption of ~~the Supply Header Project. See Notes 2 and 10~~higher lifetime capacity factors which is expected to ~~the Consolidated Financial Statements~~mitigate potential increases in ~~this report for more information.~~

~~NWP 12 Permitting~~

~~In April 2020, the U.S. District Court~~development costs such that there is no expected change to Virginia Power’s preliminary estimate for the ~~District~~project’s projected levelized cost of ~~Montana issued~~energy. Virginia Power expects to file with the Virginia Commission a request for CPCN and related rider, which filing will include an ~~order vacating an NWP 12 issued~~updated cost estimate for the project, by the ~~Army Corps~~end of Engineers and remanding the permit back to the Army Corps of Engineers for consultation under the Endangered Species Act. In 2017, the Army Corps of Engineers issued an NWP 12 authorizing discharges related to construction projects into waters of the U.S. The district court concluded that the issuance of the NWP 12 was unlawful because the Army Corps of Engineers did not consult under the Endangered Species Act with the U.S Fish and Wildlife Service and/or National Marine Fisheries Service. The district court also enjoined the Army Corps of Engineers from authorizing any dredge or fill activities under NWP 12. Following the district court’s ruling, the Army Corps of Engineers suspended the NWP 12. In May 2020, the district court amended its order to authorize the use of NWP 12 for all utility line projects other than new oil and gas pipeline projects. The Army Corps of Engineers sought emergency relief of the district court’s order from the U.S. Court of Appeals for the Ninth Circuit and the U.S. Supreme Court. In July 2020, the U.S. Supreme Court issued an order limiting the scope of the district court’s order to the construction of the Keystone XL pipeline, allowing other new oil and gas pipeline projects to use the NWP 12 process pending the appeal of the district court’s order to the U.S. Court of Appeals for the Ninth Circuit. As a result of the amended order, the cancellation of the Atlantic Coast Pipeline Project and the pending sale of its gas transmission operations to BHE, Dominion Energy does not currently expect this matter to have a material impact to its results of operations, financial position or cash flows.2021.

~~COVID-19~~

Dominion Energy ~~continues~~Virginia Solar Projects

Virginia Power has continued to ~~monitor~~identify projects to meet its renewable generation targets and currently has plans to acquire or construct several solar facilities, including the ~~global outbreak~~facilities currently under development, totaling approximately 3.6 GW of ~~COVID-19~~expected generating capacity and ~~has taken appropriate steps to mitigate the potential risks to~~ approximately $7.0 billion of investments.

Dominion Energy Virginia Battery Storage Projects

To support its ~~employees~~development of solar generation facilities, Virginia Power plans to acquire or construct multiple battery storage facilities in Virginia, with facilities currently under development totaling approximately 86 MW of storage capacity and ~~its customers posed by the spread~~approximately $160 million of ~~the virus.~~investment. These facilities are expected to be placed in service in 2022 through 2024.

Gas Distribution Non-Utility Renewable Natural Gas Projects

In August 2021, Dominion Energy provides a critical service to its customers which means that it is paramount for the company to keep its employees who operate its businesses safe and informed. For example, Dominion Energy has taken precautions with regard to employee and facility hygiene, imposed travel limitations on employees, directed employees to work remotely whenever possible and expanded health and paid time off benefits for employees. Additional protocols have been implemented for required work within customer premises to protect Dominion Energy’s employees, such customers and the public. In addition, Dominion Energy has assessed and updated its existing business continuity plans for its business units in the context of this pandemic. Working with a medical advisor, Dominion Energy developed a COVID-19 training program, which has been rolled out to employees. Dominion Energy is providing all appropriate personal protection equipment to keep employees safe and has implemented additional protections such as temperature screenings, testing services, and mandatory face covering policies. Dominion Energy is also working with suppliers to understand the potential impacts to its supply chain; however, at this time, no material risks to Dominion Energy’s supply chain have been identified. This is a rapidly evolving situation, and Dominion Energy will continue to monitor developments affecting its workforce, suppliers and other aspectsannounced an expansion of its ~~business, such as construction projects, and will take additional precautions as Dominion Energy believes are warranted. In addition, Dominion Energy continues~~partnership with Vanguard Renewables, increasing its commitment up to monitor both customer demand and its ability to collect customer receivables. While Dominion Energy currently does not expect a material impact to its results of operations from the impacts of the COVID-19 pandemic on its operations, the ultimate impacts on its results of operations, financial position and/or cash flows could be material based on the ultimate duration of the pandemic and the related economic recovery.$1 billion.

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,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 and equity security prices as described below. Commodity price risk is present in ~~Dominion Energy and Virginia Power’s~~the Companies’ electric operations and Dominion ~~Energy and Dominion Energy Gas’~~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 following sensitivity analysis estimates 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 or interest rates.

Commodity Price Risk

To manage price risk, ~~Dominion Energy and Virginia Power~~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. Dominion Energy Gas’ operations are contracted primarily under long-term fixed reservation agreements. Accordingly, management believes that Dominion Energy Gas is not subject to material commodity price risk.

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 in fair value of ~~$31~~$26 million and ~~$50~~$2 million of Dominion Energy’s commodity-based derivative instruments as of June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, respectively.

A hypothetical 10% decrease in commodity prices would have resulted in a decrease in fair value of ~~$42~~$31 million and ~~$54~~$35 million of Virginia Power’s commodity-based derivative instruments as of June 30, ~~2020~~2021 and December 31, ~~2019,~~2020, 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. They also enter into interest rate sensitive derivatives, including interest rate swaps and interest rate lock agreements. For variable rate debt outstanding for Dominion Energy and Virginia Power, ~~and Dominion Energy Gas,~~ a hypothetical 10% increase in market interest rates would not have resulted in a material change in earnings at June 30, ~~2020~~2021 or December 31, ~~2019.~~2020.

The Companies also use interest rate derivatives, including forward-starting swaps, ~~as hedges of forecasted~~ interest ~~payments.~~rate swaps and interest rate block agreements to manage interest rate risk. As of June 30, ~~2020,~~2021, Dominion Energy and Virginia Power ~~and Dominion Energy Gas~~ had ~~$8.5 billion, $2.1~~$9.2 billion and ~~$1.3~~$2.8 billion, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of ~~$95 million, $50~~$160 million and $7$115 million, respectively, in the fair value of Dominion Energy and Virginia Power ~~and Dominion Energy Gas’~~ interest rate derivatives at June 30, ~~2020.~~2021. As of December 31, ~~2019,~~2020, Dominion Energy and Virginia Power ~~and Dominion Energy Gas~~ had ~~$6.4 billion, $1.9~~$6.9 billion and ~~$1.3~~$2.1 billion, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of ~~$135 million, $88~~$124 million and ~~$17~~$75 million, respectively, in the fair value of Dominion Energy and Virginia ~~Power and Dominion Energy Gas’~~Power’s interest rate derivatives at December 31, ~~2019.~~

Dominion Energy Gas holds foreign currency swaps for the purpose of hedging the foreign currency exchange risk associated with Euro denominated debt. At both June 30, 2020 and December 31, 2019, Dominion Energy and Dominion Energy Gas had €250 million in aggregate notional amounts of these foreign currency swaps outstanding. A hypothetical 10% decrease in market interest rates would not have resulted in a material decrease in the fair value of Dominion Energy Gas’ foreign currency swaps at June 30, 2020 or December 31, 2019.2020.

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.

Investment Price Risk

~~Dominion Energy and Virginia Power~~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 ~~Dominion Energy and Virginia Power’s~~the Companies’ Consolidated Balance Sheets at fair value.

Dominion Energy recognized net investment gains (including investment income) on nuclear decommissioning and rabbi trust investments of $675 million for the six months ended June 30, 2021, net investment losses (including investment income) on nuclear decommissioning and rabbi trust investments of $207 million for the six months ended June 30, 2020, and net investment gains (including investment income) on nuclear decommissioning and rabbi trust investments of ~~$603~~$662 million ~~for the six months ended June 30, 2019 and $1.0 billion~~ for the year ended December 31, ~~2019.~~2020. Net realized gains and losses include gains and losses from the sale of ~~investments in both 2020 and 2019 as well as any other-than-temporary declines in fair value in 2019 only.~~investments. Dominion Energy recorded in AOCI and regulatory liabilities, a net decrease in unrealized gains on debt investments of $41 million for the six months ended June 30, 2021 and a net increase in unrealized gains on debt investments of $37 million and ~~$65~~$57 million for the six months ended June 30, 2020 and ~~2019, respectively, and $74 million for~~ the year ended December 31, ~~2019.~~2020, respectively.

Virginia Power recognized net investment gains (including investment income) on nuclear decommissioning and rabbi trust investments of $327 million for the six months ended June 30, 2021, net investment losses (including investment income) on nuclear decommissioning and rabbi trust investments of $119 million for the six months ended June 30, 2020, and net investment gains (including investment income) on nuclear decommissioning and rabbi trust investments of ~~$282 million for the six months ended June 30, 2019 and $481~~$287 million for the year ended December 31, ~~2019.~~2020. Net realized gains and losses include gains and losses from the sale of ~~investments in both 2020 and 2019 as well as any other-than-temporary declines in fair value in 2019 only.~~investments. Virginia Power recorded in AOCI and regulatory liabilities, a net decrease in unrealized gains on debt investments of $12 million for the six months ended June 30, 2021 and a net increase in unrealized gains on debt investments of $20 million and ~~$31~~$29 million for the six months ended June 30, 2020 and ~~2019, respectively, and $30 million for~~ the year ended December 31, ~~2019.~~2020, respectively.

Dominion Energy sponsors pension and other postretirement employee benefit plans that hold investments in trusts to fund employee benefit payments. Virginia Power ~~and Dominion Energy Gas~~ employees participate in these plans. Differences between actual and expected returns on plan assets are accumulated and amortized during future periods. As such, any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for employee benefit plans and will be included in the determination of the amount of cash to be contributed to the employee benefit plans.

ITEM 4. CONTROLS AND PROCEDURES

Senior management of ~~each of~~both Dominion Energy and Virginia Power, ~~and Dominion Energy Gas,~~ including Dominion Energy and Virginia ~~Power and Dominion Energy Gas’~~Power’s CEO and CFO, evaluated the effectiveness of each ~~of their respective~~ 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 and Dominion Energy Gas’~~Power’s CEO and CFO have concluded that each ~~of their respective~~ 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 or Dominion Energy Gas’~~Power’s internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, the Companies are ~~alleged~~parties to ~~be in violation~~various legal, environmental or in default under orders, statutes, rules or regulations relating to the environment, compliance plans imposed upon or agreed to by the Companies, or permits issued by various local, state and/or federal agencies for the construction or operation of facilities. Administrativeother regulatory proceedings, ~~may also be pending on these matters. In addition,~~including in the ordinary course of ~~business,~~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 ~~and their subsidiaries are involved in various legal~~reasonably believe will exceed a specified threshold. Pursuant to the SEC regulations, the Companies use a threshold of $1 million for such proceedings.

In March 2018, Virginia Power received a proposed consent order from the VDEQ in connection with alleged CWA permit violations at the Chesterfield power station in 2017. Virginia Power began working cooperatively with both the VDEQ and the EPA to resolve those and certain other alleged violations collectively. In March 2020, Virginia Power finalized a consent decree with the VDEQ and the EPA that would require Virginia Power to pay a $1.4 million civil penalty in connection with various alleged CWA permit and other violations. In July 2020, the consent decree was entered by order of the U.S. District Court for the Eastern District of Virginia.

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, ~~2019.~~

•	~~Notes 13 and 17 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020.

•	Notes 13 and 17 to the Consolidated Financial Statements in this report.

ITEM 1A. RISK FACTORS

The Companies’ businesses are influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond the Companies’ control. A number of these risk factors have been identified in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2019 and updated in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020, 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, ~~2019 and the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2020. 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

~~ISSUER PURCHASES OF EQUITY SECURITIES~~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⁾

~~4/1/20-4/30/20~~

—

~~19,629,059 shares/~~

~~$1.18 billion~~

~~5/1/20-5/31/20~~

—

~~19,629,059 shares/~~

~~$1.18 billion~~

~~6/1/20-6/30/20~~

—

~~19,629,059 shares/~~

~~$1.18 billion~~

~~Total~~

—

~~19,629,059 shares/~~

~~$1.18 billion~~

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⁾
4/1/21 - 4/30/21		2,181	$	75.70		—	$ 0.92 billion
5/1/21 - 5/31/21		—		—		—	0.92 billion
6/1/21 - 6/30/21		—		—		—	0.92 billion
Total		2,181	$	75.70		—	$ 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)

~~The remaining repurchase authorization is pursuant to repurchase authority granted by~~In November 2020, the Dominion Energy Board of Directors ~~in February 2005, as~~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, ~~in June 2007. The aggregate authorization granted by~~suspended or terminated at any time. Shares may be purchased through open market or privately negotiated transactions or otherwise at the ~~Dominion Energy Board~~discretion of ~~Directors was 86 million shares (as adjusted~~management subject to ~~reflect a two-for-one stock split distributed in November 2007) not to exceed $4 billion.~~prevailing market conditions, applicable securities laws and other factors.

~~In July~~ITEM 5. OTHER INFORMATION

On August 6, 2021, Dominion Energy filed a prospectus supplement to its effective registration statement on Form S-3 (File No. 333-239467) filed with the SEC on June 26, 2020 for purposes of registering the ~~Board~~offer and resale of ~~Directors authorized the repurchase~~certain shares of ~~up to $3.0 billion of Dominion Energy’s~~its common stock previously issued and ~~rescinded~~delivered to SCDOR in accordance with the ~~prior two authorizations from 2005~~terms of a settlement agreement as discussed in Note 17 to the Consolidated Financial Statements in this report. The registration rights agreement and ~~2007.~~ ~~The repurchase program does not include a specific timetable or price or volume targets~~opinion of counsel relating to the registration and ~~may be modified, suspended or terminated at any time. Shares may be purchased through open market or privately negotiated transactions or otherwise at~~validity of such shares are filed as Exhibits 4.1 and 5.1, respectively, to this Quarterly Report on Form 10-Q for the ~~discretion~~purpose of ~~management subject to prevailing market~~ ~~conditions, applicable securities laws~~incorporating such exhibits by reference into the registration statement and ~~other factors.~~the related prospectus contained therein, as supplemented by the prospectus supplement.

ITEM 6. EXHIBITS

Exhibit

Number

Description

Dominion Energy

Virginia Power

~~Dominion Energy Gas~~

~~2.1~~

Purchase and Sale Agreement, dated as of July 3, 2020, by and among Dominion Energy, Inc., Dominion Energy Questar Corporation and Berkshire Hathaway Energy Company (Exhibit 2.1, Form 8-K filed July 6, 2020, File No. 1-8489).

3.1.a

Dominion Energy, Inc. Articles of Incorporation, as restated, effective December 13, 2019 (Exhibit 3.1, Form 8-K filed December 13, 2019, File No.1-8489).

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).

~~3.1.c~~

~~Articles of Organization of Dominion Energy Gas Holdings, LLC (Exhibit 3.1, Form S-4 filed April 4, 2014, File No. 333-195066).~~

~~3.1.d~~

~~Articles of Amendment to the Articles of Organization of Dominion Energy Gas Holdings, LLC (Exhibit 3.1, Form 8-K filed May 16, 2017, File No. 1-37591).~~

3.2.a

Dominion Energy, Inc. Bylaws, as amended and restated, effective ~~July 30, 2020~~May 5, 2021 (Exhibit 3.1, Form 8-K filed ~~July 31, 2020,~~May 6, 2021, File No. 1-8489).

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).

~~3.2.c~~

~~Operating Agreement of Dominion Energy Gas Holdings, LLC, as amended and restated, effective November 5, 2019 (Exhibit 3.1, Form 8-K filed November 12, 2019, File No. 001-37591).~~

~~4.1~~4

Dominion Energy, Inc., and Virginia Electric and Power Company ~~and Dominion Energy Gas Holdings, LLC~~ agree to furnish to the ~~U.S.~~ 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.

4.1

Registration Rights Agreement, dated August 6, 2021, by and between Dominion Energy, Inc. and South Carolina Department of Revenue (filed herewith).

5.1

Opinion of McGuireWoods LLP (filed herewith).

10.1

$6,000,000,000 Fifth Amended and Restated Revolving Credit Agreement, dated June 9, 2021, among Dominion Energy, Inc., Virginia Electric and Power Company, Questar Gas Company, Dominion Energy South Carolina, Inc., JPMorgan Chase Bank, N.A., as Administrative Agent, Mizuho Bank, Ltd., Bank of America, N.A., The Bank of Nova Scotia and Wells Fargo Bank, N.A., as Syndication Agents, J.P. Morgan Securities LLC and Mizuho Bank, Ltd., as Co-Sustainability Structuring Agent, and other lenders named therein (Exhibit 10.1, Form 8-K filed June 10, 2021, File No. 1-8489).

10.2

$900,000,000 Sustainability Revolving Credit Agreement, dated as of June 9, 2021, among Dominion Energy, Inc., Sumitomo Mitsui Banking Corporation, as Administrative Agent and Sustainability Coordinator, Sumitomo Mitsui Banking Corporation, The Bank of Nova Scotia and The Toronto- Dominion Bank, New York Branch, as Joint Lead Arrangers and Joint Bookrunners, and the other lenders named therein (Exhibit 10.2, Form 8-K filed June 10, 2021, File No. 1-8489).

~~4.2~~

~~Exhibit~~

~~Number~~10.3

~~Description~~$1,265,341,250 364-Day Term Loan Credit Agreement, dated as of July 14, 2021, by and among Dominion Energy, Inc., as Borrower, Barclays Bank PLC (Barclays), as Administrative Agent, Barclays, as Sole Lead Arranger and Sole Bookrunner, and the other lenders from time to time parties thereto (Exhibit 10.1, Form 8-K filed July 14, 2021, File No. 1-8489).

~~Dominion Energy~~X

~~Virginia Power~~

~~Dominion Energy Gas~~

31.a

Certification by Chief Executive Officer of Dominion Energy, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).

31.b

Certification by Chief Financial Officer of Dominion Energy, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).

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).

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).

~~31.e~~

~~Certification by Chief Executive Officer of Dominion Energy Gas Holdings, LLC pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).~~

~~31.f~~

~~Certification by Chief Financial Officer of Dominion Energy Gas Holdings, LLC pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).~~

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).

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).

Exhibit

Number

Description

Dominion Energy

Virginia Power

~~32.c~~

Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion Energy Gas Holdings, LLC as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).

Condensed consolidated earnings statements (filed herewith).

101

The following financial statements from Dominion Energy, Inc.’s Quarterly Report on Form 10-Q for the quarter ended June 30, ~~2020,~~2021, filed on August ~~5, 2020,~~6, 2021, 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 June 30, ~~2020,~~2021, filed on August ~~5, 2020,~~6, 2021, 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 Common Shareholder’s Equity (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements. The following financial statements from Dominion Energy Gas Holdings, LLC’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2020, filed on August 5, 2020, 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.

104

Cover Page Interactive Data File formatted in iXBRL (Inline eXtensible Business Reporting Language) and contained in Exhibit 101.

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

August ~~5, 2020~~6, 2021	/s/ Michele L. Cardiff
	Michele L. Cardiff Senior Vice President, Controller and Chief Accounting Officer

	VIRGINIA ELECTRIC AND POWER COMPANY Registrant

August ~~5, 2020~~6, 2021	/s/ Michele L. Cardiff
	Michele L. Cardiff Senior Vice President, Controller and Chief Accounting Officer

	~~DOMINION ENERGY GAS HOLDINGS, LLC~~ ~~Registrant~~

~~August 5, 2020~~	~~/s/ Michele L. Cardiff~~
	~~Michele L. Cardiff~~ ~~Vice President, Controller and~~ ~~Chief Accounting Officer~~

~~130~~100

	Predecessor Equity			Membership Interests			AOCI			Total Members' Equity			Noncontrolling Interests			Total
(millions)
March 31, 2019	$	2,938		$	4,682		$	(191	)	$	7,429		$	1,432		$	8,861
Net income		72			47						119			30			149
Dividends and distributions		(153	)								(153	)		(36	)		(189	)
Other comprehensive income, net of tax								5			5						5
Other		2									2						2
June 30, 2019	$	2,859		$	4,729		$	(186	)	$	7,402		$	1,426		$	8,828

March 31, 2020	$	—		$	8,968		$	(271	)	$	8,697		$	1,381		$	10,078
Net income (loss)					(198	)					(198	)		32			(166	)
Dividends and distributions					(1,418	)					(1,418	)		(38	)		(1,456	)
June 30, 2020	$	—		$	7,352		$	(271	)	$	7,081		$	1,375		$	8,456

	Three Months Ended June 30, 2019⁽¹⁾		Six Months Ended June 30, 2019⁽¹⁾
(millions, except EPS)
Operating Revenue	$	3,970	$	8,835
Net income attributable to Dominion Energy		392		962
Earnings Per Common Share – Basic	$	0.49	$	1.21
Earnings Per Common Share – Diluted	$	0.47	$	1.19

	Three Months Ended June 30, 2019		Six Months Ended June 30, 2019
(millions)
Operating revenue	$	154	$	383
Depreciation and amortization		22		43
Other operating expenses		128		277
Other income		18		37
Interest and related charges		8		18
Income tax expense		3		17
Net income from discontinued operations	$	11	$	65

	Current		Noncurrent
Interest rate⁽¹⁾	$	750,000,000	$	550,000,000
Foreign currency⁽¹⁾	€	-	€	250,000,000

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(158	)	$	(11	)	294 months
Foreign currency		(10	)		(4	)	72 months
Total	$	(168	)	$	(15	)

	Fair Value- Derivatives Under Hedge Accounting		Fair Value-Derivatives Not Under Hedge Accounting		Total Fair Value
(millions)
June 30, 2020
LIABILITIES
Current Liabilities
Interest rate	$	58	$	13	$	71
Foreign currency		5		—		5
Total current derivative liabilities⁽²⁾		63		13		76
Noncurrent Liabilities
Interest rate		121		—		121
Foreign currency		7		—		7
Total noncurrent derivative liabilities⁽³⁾		128		—		128
Total derivative liabilities	$	191	$	13	$	204
December 31, 2019
ASSETS
Noncurrent Assets
Foreign currency	$	8	$	—	$	8
Total noncurrent derivative assets⁽¹⁾		8		—		8
Total derivative assets	$	8	$	—	$	8
LIABILITIES
Current Liabilities
Interest rate	$	30	$	—	$	30
Foreign currency		3		—		3
Total current derivative liabilities⁽²⁾		33		—		33
Noncurrent Liabilities
Interest rate		53		—		53
Total noncurrent derivative liabilities⁽³⁾		53		—		53
Total derivative liabilities	$	86	$	—	$	86

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
(millions)
Three Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	(4	)	$	(4	)
Foreign currency⁽³⁾		5			6
Total	$	1		$	2
Three Months Ended June 30, 2019
Derivative type and location of gains (losses):
Commodity:
Net income from discontinued operations				$	—
Total commodity	$	3		$	—
Interest rate⁽²⁾		(36	)		(2	)
Foreign currency⁽³⁾		1			4
Total	$	(32	)	$	2
Six Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽²⁾		(105	)		(6	)
Foreign currency⁽³⁾		(17	)		—
Total	$	(122	)	$	(6	)
Six Months Ended June 30, 2019
Derivative type and location of gains (losses):
Commodity:
Net income from discontinued operations				$	2
Total commodity	$	2		$	2
Interest rate⁽²⁾		(60	)		(1	)
Foreign currency⁽³⁾		(10	)		(2	)
Total	$	(68	)	$	(1	)

Derivatives not designated as hedging instruments	Amount of Gain (Loss) Recognized in Income on Derivatives
	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2020		2019		2020			2019
(millions)
Derivative type and location of gains (losses):
Interest rate⁽¹⁾	$	—	$	—	$	(8	)	$	—
Total	$	—	$	—	$	(8	)	$	—

Description and Location of Project	Application Date	Approval Date	Type of Line	Miles of Lines	Cost Estimate (millions)
Rebuild and operate five segments between the Loudoun and Ox substations	August 2019	June 2020	230 kV	19	70
Rebuild and operate two lines in Chesterfield County, Virginia	January 2020	June 2020	230 kV	3	15
Bristers-Ladysmith Rebuild Project in the counties of Fauquier, Stafford, Spotsylvania, and Caroline, Virginia	May 2020	Pending	500 kV	37	110