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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended ~~September~~June 30, ~~2019~~2020

☐	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
~~DOMINION ENERGY GAS~~ ~~HOLDINGS, LLC~~	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 ~~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 ~~October 11, 2019,~~July 17, 2020, the latest practicable date for determination, Dominion Energy, Inc. had ~~823,093,381~~840,135,854 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., Virginia Electric and Power Company and Dominion Energy Gas Holdings, LLC. 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 no representations as to the information relating to Dominion Energy, Inc.’s other operations.

VIRGINIA ELECTRIC AND POWER COMPANY AND DOMINION ENERGY GAS HOLDINGS, LLC MEET THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION H(1)(a) AND (b) OF FORM 10-Q AND ARE 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	89
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	~~106~~105
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	124
Item 4.	Controls and Procedures	125

	PART II. Other Information	126

Item 1.	Legal Proceedings	126
Item 1A.	Risk Factors	126
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	126
Item 6.	Exhibits	~~127~~128

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
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 ~~and Southern Company Gas~~Energy
Atlantic Coast Pipeline Project		~~The~~A previously proposed approximately 600-mile natural gas pipeline running from West Virginia through Virginia to North Carolina which ~~will be~~would have been owned by Dominion Energy and Duke ~~and Southern Company Gas~~Energy and constructed and operated by DETI
BACT		Best available control technology
~~Bankruptcy Court~~		~~U.S. Bankruptcy Court for the Southern District of New York~~
bcf		Billion cubic feet
Bear Garden		A 590 MW combined-cycle, natural gas-fired power station in Buckingham County, Virginia
BHE		Berkshire Hathaway Energy Company
Blue Racer		Blue Racer Midstream, LLC, a joint venture between Caiman Energy II, LLC and FR BR Holdings, LLC ~~effective December 2018~~
BP		BP Wind Energy North America Inc.
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
~~CAISO~~CARES Act		~~California Independent System Operator~~Coronavirus Aid, Relief and Economic Security Act, enacted on March 27, 2020
CCR		Coal combustion residual
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, Virginia Power and Dominion Energy Gas, collectively

~~Abbreviation or Acronym~~Contracted Generation		~~Definition~~Contracted Generation 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		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
CPCN		Certificate of Public Convenience and Necessity
CWA		Clean Water Act
DCP		The legal entity, Dominion Cove Point, LLC, one or more of its consolidated subsidiaries, or the entirety of Dominion Cove Point, LLC and its consolidated subsidiaries
DECG		Dominion Energy Carolina Gas Transmission, ~~LLC~~Inc.
DECGS		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. ~~(formerly known as South Carolina Electric & Gas Company)~~, one or more of its consolidated ~~subsidiaries~~entities or operating ~~segments,~~segment, or the entirety of Dominion Energy South Carolina, Inc. and its consolidated ~~subsidiaries~~entities
DETI		Dominion Energy Transmission, Inc.
DGI		Dominion Generation, Inc.
DGP		Dominion Gathering and Processing, Inc.
DMLPHCII		Dominion MLP Holding Company II, 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) or operating segments, or the entirety of Dominion Energy, Inc. and its consolidated subsidiaries
Dominion Energy Gas		The legal entity, Dominion Energy Gas Holdings, LLC, one or more of its consolidated subsidiaries or operating segment, or the entirety of Dominion 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, Dominion Energy Midstream Partners, LP, one or more of its consolidated subsidiaries, ~~Cove Point GP Holding Company, LLC, Iroquois GP Holding Company, LLC, DECG and Dominion Energy Questar Pipeline,~~ or the entirety of Dominion Energy 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, 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
DSM		Demand-side management
Dth		Dekatherm
Duke Energy		The legal entity, Duke Energy Corporation, one or more of its consolidated subsidiaries, or ~~operating segments, or~~ the entirety of Duke Energy Corporation and its consolidated subsidiaries

East Ohio		The East Ohio Gas Company, doing business as Dominion Energy Ohio
~~Eastern Market Access Project~~		~~Project to provide 150,000 Dths/day of transportation service to help meet demand for natural gas for Washington Gas Light Company, a local gas utility serving customers in D.C., Virginia and Maryland~~
EPA		U.S. Environmental Protection Agency
EPS		Earnings per share
~~FASB~~Export Customers		~~Financial Accounting Standards Board~~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 ~~effective August 2018~~
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 ~~Infrastructure~~Distribution		Gas ~~Infrastructure Group~~Distribution operating segment
Gas Transmission & Storage		Gas Transmission & Storage operating segment
GENCO		South Carolina Generating Company, Inc.
GHG		Greenhouse gas

~~Abbreviation or Acronym~~		~~Definition~~
GIP		The legal entity, Global Infrastructure Partners, one or more of its consolidated subsidiaries, ~~(including, effective August 2018, Four Brothers Holdings, LLC, Granite Mountain Renewables, LLC, and Iron Springs Renewables, LLC) or operating segments,~~ 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 ~~effective August 2018~~
~~GreenHat~~Grassfield Solar		~~GreenHat Energy, LLC~~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
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 ~~effective August 2018~~
Iroquois		Iroquois Gas Transmission System, L.P.
~~ISO-NE~~ISO		~~ISO New England, Inc.~~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		A natural gas export/liquefaction facility at the Cove Point LNG Facility
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 ~~new~~ nuclear development project under which ~~SCANA~~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 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
~~ODEC~~		~~Old Dominion Electric Cooperative~~
Ohio Commission		Public Utilities Commission of Ohio
Order 1000		Order issued by FERC adopting requirements for electric transmission planning, cost allocation and development
~~PIPP~~Overthrust		~~Percentage of Income Payment Plan deployed by East Ohio~~Dominion Energy Overthrust Pipeline, L.L.C.
PIR		Pipeline Infrastructure Replacement program deployed by East Ohio
PJM		PJM Interconnection, L.L.C.

~~Abbreviation or Acronym~~Predecessor		~~Definition~~
~~Power Delivery~~		~~Power Delivery Group operating segment~~
~~Power Generation~~		~~Power Generation Group operating segment~~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
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
~~PURA~~		~~Connecticut’s Public Utility Regulatory Authority~~
Questar Gas		Questar Gas Company, doing business as Dominion Energy Utah, Dominion Energy Wyoming and Dominion Energy Idaho
RCC		Replacement Capital Covenant
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 EGV		A rate adjustment clause associated with the recovery of costs related to ~~certain capital projects at~~Greensville County

Rider R		A rate adjustment clause associated with the recovery of costs related to Bear Garden
Rider S		A rate adjustment clause associated with the recovery of costs related to the Virginia ~~Power’s electric generating stations~~City Hybrid Energy Center
Rider T1		A rate adjustment clause to ~~comply with federal~~recover the difference between revenues produced from transmission rates included in base rates and ~~state environmental laws and regulations~~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 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
~~Southeast Energy~~Southampton		~~Southeast Energy Group operating segment~~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 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		A partnership comprised primarily of institutional investors advised by J.P. Morgan Asset Management-Global Real Assets
Three Cedars		Granite Mountain and Iron Springs, collectively

~~Abbreviation or Acronym~~Utah Commission		~~Definition~~Utah Public Service Commission
~~UEX~~ ~~Utah Commission~~VCEA		~~Uncollectible Expense Rider deployed~~Virginia Clean Economy Act, passed by ~~East Ohio~~ ~~Utah Public Service Commission~~the Virginia General Assembly in March 2020 and enacted on April 11, 2020
VDEQ		Virginia Department of Environmental Quality
VEBA		Voluntary ~~Employees'~~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 ~~segments,~~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. ~~(formerly known as Stone & Webster, Inc.)~~, a wholly-owned subsidiary of Westinghouse
West Virginia Commission		Public Service Commission of West Virginia
Westinghouse		Westinghouse Electric Company LLC
~~Whitehouse~~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
Woodland Solar		A 19 MW utility-scale solar power station in Isle of Wight County, Virginia
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 September 30,				Nine Months Ended September 30,				Three Months Ended June 30,					Six Months Ended June 30,
	2019		2018		2019		2018		2020			2019		2020			2019
(millions, except per share amounts)
Operating Revenue⁽¹⁾	$	4,269	$	3,451	$	12,097	$	10,005	$	3,585		$	3,970	$	8,081		$	7,828
Operating Expenses
Electric fuel and other energy-related purchases		774		761		2,283		2,128		505			718		1,173			1,509
Purchased electric capacity		11		50		74		87		11			24		13			63
Purchased gas		153		5		1,110		409		74			227		501			957
Other operations and maintenance		1,010		770		3,295		2,438		995			1,283		2,038			2,285
Depreciation, depletion and amortization		679		526		1,991		1,487		673			661		1,346			1,312
Other taxes		243		177		819		542		256			284		540			576
Impairment of assets and other charges		85		12		1,232		147		531			312		1,299			1,147
Total operating expenses		2,955		2,301		10,804		7,238		3,045			3,509		6,910			7,849
Income from operations		1,314		1,150		1,293		2,767
Income (loss) from operations										540			461		1,171			(21	)
Earnings (loss) from equity method investees										(2,281	)		39		(2,228	)		80
Other income		173		373		653		658		502			53		50			400
Interest and related charges		451		378		1,372		1,053		449			452		939			921
Income from operations including noncontrolling interests before income tax expense		1,036		1,145		574		2,372
Income tax expense		51		262		208		485
Net Income Including Noncontrolling Interests		985		883		366		1,887
Income (loss) from operations including noncontrolling interests before income tax expense (benefit)										(1,688	)		101		(1,946	)		(462	)
Income tax expense (benefit)										(556	)		43		(575	)		157
Net Income (Loss) Including Noncontrolling Interests										(1,132	)		58		(1,371	)		(619	)
Noncontrolling Interests		10		29		17		81		37			4		68			7
Net Income Attributable to Dominion Energy	$	975	$	854	$	349	$	1,806
Net Income (Loss) Attributable to Dominion Energy									$	(1,169	)	$	54	$	(1,439	)	$	(626	)
Earnings Per Common Share
Net income attributable to Dominion Energy - Basic	$	1.19	$	1.31	$	0.42	$	2.77
Net income attributable to Dominion Energy - Diluted		1.17		1.30		0.39		2.77
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	)

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

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 September 30,						Nine Months Ended September 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Net income including noncontrolling interests	$	985		$	883		$	366		$	1,887
Net income (loss) including noncontrolling interests													$	(1,132	)	$	58		$	(1,371	)	$	(619	)
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		(107	)		(27	)		(209	)		51			2			(78	)		(264	)		(102	)
Changes in unrealized net gains (losses) on investment securities⁽²⁾		8			(6	)		37			(24	)		19			13			28			29
Changes in net unrecognized pension and other postretirement benefit costs⁽³⁾		(4	)		—			109			—			(1	)		113			(1	)		113
Amounts reclassified to net income:
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities⁽⁴⁾		(6	)		30			(58	)		71			5			(21	)		27			(52	)
Net realized (gains) losses on investment securities⁽⁵⁾		(4	)		3			(5	)		4			(5	)		(1	)		(14	)		(1	)
Net pension and other postretirement benefit costs⁽⁶⁾		20			18			50			60			18			22			37			30
Changes in other comprehensive income from equity method investees⁽⁷⁾		(1	)		—			(1	)		1
Total other comprehensive income (loss)		(94	)		18			(77	)		163			38			48			(187	)		17
Comprehensive income including noncontrolling interests		891			901			289			2,050
Comprehensive income (loss) including noncontrolling interests														(1,094	)		106			(1,558	)		(602	)
Comprehensive income attributable to noncontrolling interests		10			29			17			82			37			4			68			7
Comprehensive income attributable to Dominion Energy	$	881		$	872		$	272		$	1,968
Comprehensive income (loss) attributable to Dominion Energy													$	(1,131	)	$	102		$	(1,626	)	$	(609	)

(1)

Net of ~~$37~~$(4) million and $9$27 million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and net of ~~$69~~$89 million and ~~$(17)~~$32 million tax for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively.

(2)

Net of ~~$(2)~~$(6) million and $1$(5) million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and net net of ~~$(13)~~$(10) million and $7$(11) million tax for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, 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.

Net of $4 million and $— million tax for the three months ended September 30, 2019 and 2018, respectively, and net of $(45) million and $— million tax for the nine months ended September 30, 2019 and 2018, respectively.

~~(4)~~

Net of $1 million and $(10) million tax for the three months ended September 30, 2019 and 2018, respectively, and net of $19 million and $(24) million tax for the nine months ended September 30, 2019 and 2018, respectively.

~~(5)~~

Net of $1 million and $— million tax for the three months ended September 30, 2019 and 2018, respectively, and net of $1 million and $(1) million tax for the nine months ended September 30, 2019 and 2018, respectively.

~~(6)~~

Net of $(6) million and $(7) million tax for the three months ended September 30, 2019 and 2018, respectively, and net of $(17) million and $(15) million tax for the nine months ended September 30, 2019 and 2018, respectively.

~~(7)~~

~~Net of $— million tax for both the three months ended September 30, 2019 and 2018, and net of $— million and $(1) million tax for the nine months ended September 30, 2019 and 2018, respectively.~~

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

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2019			December 31, 2018⁽¹⁾			June 30, 2020			December 31, 2019⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	378		$	268		$	675		$	166
Customer receivables (less allowance for doubtful accounts of $19 and $14)		1,972			1,749
Other receivables (less allowance for doubtful accounts of $3 and $4)⁽²⁾		363			331
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
Inventories		1,800			1,418			1,735			1,742
Prepayments								589			328
Regulatory assets		966			496			616			879
Derivative assets		55			223
Prepayments		338			265
Assets held for sale		228			—
Other		169			411			236			328
Total current assets		6,269			5,161			6,124			6,088
Investments
Nuclear decommissioning trust funds		5,860			4,938			6,018			6,192
Investment in equity method affiliates		1,528			1,278			584			1,646
Other		369			344			382			379
Total investments		7,757			6,560			6,984			8,217
Property, Plant and Equipment
Property, plant and equipment		96,122			76,578			96,527			97,466
Accumulated depreciation, depletion and amortization		(28,144	)		(22,018	)		(28,547	)		(28,384	)
Total property, plant and equipment, net		67,978			54,560			67,980			69,082
Deferred Charges and Other Assets
Goodwill		8,986			6,410			8,946			8,946
Intangible assets, net		773			670
Regulatory assets		7,669			2,676			9,438			7,687
Operating lease assets		455			—
Pension and other postretirement benefit assets		1,610			1,279
Other		862			598			4,256			3,803
Total deferred charges and other assets		20,355			11,633			22,640			20,436
Total assets	$	102,359		$	77,914		$	103,728		$	103,823

(1)	Dominion Energy’s Consolidated Balance Sheet at December 31, ~~2018~~2019 has been derived from the audited Consolidated Balance Sheet at that date.

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

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

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	September 30, 2019			December 31, 2018⁽¹⁾			June 30, 2020			December 31, 2019⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	4,824		$	3,624		$	2,799		$	3,162
Credit facility borrowings		—			73
Supplemental 364-Day credit facility borrowings								225			—
Short-term debt		2,420			334			386			911
Accounts payable		791			914			797			1,115
Accrued interest, payroll and taxes		1,263			836			1,011			1,323
Regulatory liabilities		547			356			749			497
Liabilities held for sale		85			—
Reserves for SCANA legal proceedings								538			696
Derivative liabilities								586			408
Other⁽²⁾		2,261			1,510			2,446			1,827
Total current liabilities		12,191			7,647			9,537			9,939
Long-Term Debt
Long-term debt		29,838			26,328			33,844			30,313
Junior subordinated notes		3,797			3,430			2,858			3,406
Remarketable subordinated notes		—			1,386
Other								444			105
Total long-term debt		33,635			31,144			37,146			33,824
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		6,198			5,116			5,921			6,277
Regulatory liabilities		10,926			6,840			10,680			11,001
Asset retirement obligations		5,020			2,250
Operating lease liabilities		394			—
Pension and other postretirement benefit liability		2,571			2,328
Other		1,467			541
Derivative liabilities								748			332
Other⁽²⁾								8,812			8,417
Total deferred credits and other liabilities		26,576			17,075			26,161			26,027
Total liabilities		72,402			55,866			72,844			69,790
Commitments and Contingencies (see Note 18)
Commitments and Contingencies (see Note 17)
Equity
Preferred stock⁽³⁾		1,596			—
Common stock – no par⁽⁴⁾		22,131			12,588
Preferred stock (See Note 16)								2,387			2,387
Common stock – no par⁽³⁾								23,984			23,824
Retained earnings		7,336			9,219			4,480			7,576
Accumulated other comprehensive loss		(1,777	)		(1,700	)		(1,980	)		(1,793	)
Total shareholders' equity		29,286			20,107			28,871			31,994
Noncontrolling interests		671			1,941			2,013			2,039
Total equity		29,957			22,048			30,884			34,033
Total liabilities and equity	$	102,359		$	77,914		$	103,728		$	103,823

(1)	~~Dominion Energy’s Consolidated Balance Sheet at December 31, 2018 has been derived from the audited Consolidated Balance Sheet at that date.~~

~~(2)~~

~~See Note 10 for amounts attributable to related parties.~~

~~(3)~~

~~20 million shares authorized; 2 million shares outstanding at September 30, 2019.~~

~~(4)~~

~~1.8 billion shares authorized and 823 million shares outstanding at September 30, 2019 and 1.0 billion shares authorized and 681 millionshares outstanding at December 31, 2018.~~

~~The accompanying notes are an integral part of~~ Dominion Energy’s Consolidated ~~Financial Statements.~~Balance Sheet at December 31, 2019 has been derived from the audited Consolidated Balance Sheet at that date.

~~DOMINION ENERGY, INC.~~(2) See Note 10 for amounts attributable to related parties.

~~CONSOLIDATED STATEMENTS OF EQUITY - QUARTER-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)

June 30, 2018

—

$
—

654

$
10,782

$
8,820

$
(1,538
)

$
18,064

$
1,972

$
20,036

Net income including noncontrolling
     interests

854

854

29

883

Issuance of stock

1

75

75

75

Stock awards (net of change in unearned
   compensation)

5

5

5

Dividends ($0.8350 per common share)
   and distributions

(546
)

(546
)

(45
)

(591
)
Other comprehensive income, net of tax

18

18

18

September 30, 2018

—

$
—

655

$
10,862

$
9,128

$
(1,520
)

$
18,470

$
1,956

$
20,426

June 30, 2019

2

$
1,596

803

$
20,660

$
7,124

$
(1,683
)

$
27,697

$
684

$
28,381

Net income including noncontrolling
   interests

975

975

10

985

Issuance of stock

20

1,477

1,477

1,477

Stock awards (net of change in unearned
   compensation)

7

7

7

Preferred stock dividends ($4.375 per
   share)

(7
)

(7
)

(7
)
Common stock dividends ($0.9175 per
   share) and distributions

(755
)

(755
)

(23
)

(778
)
Other comprehensive loss, net of tax

(94
)

(94
)

(94
)
Other

(13
)

(1
)

(14
)

(14
)
September 30, 2019

2

$
1,596

823

$
22,131

$
7,336

$
(1,777
)

$
29,286

$
671

$
29,957

(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 - ~~YEAR-TO-DATE~~QUARTER-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, 2017

—

$
—

645

$
9,865

$
7,936

$
(659
)

$
17,142

$
2,228

$
19,370

Cumulative-effect of changes in
   accounting principles

(127
)

1,029

(1,023
)

(121
)

127

6

Net income including noncontrolling
     interests

1,806

1,806

81

1,887

Issuance of stock

10

737

737

737

Sale of Dominion Energy Midstream
   common units - net of offering costs

—

4

4

Remeasurement of noncontrolling
   interest in Dominion Energy
   Midstream

375

375

(375
)

—

Stock awards (net of change in unearned
   compensation)

17

17

17

Dividends ($2.505 per common share)
   and distributions

(1,635
)

(1,635
)

(110
)

(1,745
)
Other comprehensive income, net of tax

162

162

1

163

Other

(5
)

(8
)

(13
)

(13
)
September 30, 2018

—

$
—

655

$
10,862

$
9,128

$
(1,520
)

$
18,470

$
1,956

$
20,426

December 31, 2018

—

$
—

681

$
12,588

$
9,219

$
(1,700
)

$
20,107

$
1,941

$
22,048

Net income including
   noncontrolling interests

349

349

17

366

Issuance of stock

2

1,596

24

1,802

3,398

3,398

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)

19

19

19

Preferred stock dividends ($5.104 per
   share)

(8
)

(8
)

(8
)
Common stock dividends ($2.753 per
   share) and distributions

(2,224
)

(2,224
)

(66
)

(2,290
)
Other comprehensive loss, net of tax

(77
)

(77
)

(77
)
Other

(13
)

(13
)

(13
)
September 30, 2019

2

$
1,596

823

$
22,131

$
7,336

$
(1,777
)

$
29,286

$
671

$
29,957

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

~~(1)~~

(1) See Note 16 for further information.

~~See Note 17 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

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 CASH FLOWS

(Unaudited)

Nine Months Ended September 30,	2019			2018
Six Months Ended June 30,							2020			2019
(millions)
Operating Activities
Net income including noncontrolling interests	$	366		$	1,887
Adjustments to reconcile net income including noncontrolling interests to net cash provided by 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)		2,235			1,706			1,497			1,472
Deferred income taxes and investment tax credits		112			486			(231	)		107
Provision for refunds and rate credits to electric utility customers		936			77			—			953
Impairment of assets and other charges		982			139			1,297			1,012
Loss for equity method investee								2,315			—
Charge related to a voluntary retirement program		384			—			—			409
Gains on sales of assets and equity method investments		(20	)		(196	)
Net gains on nuclear decommissioning trust funds and other investments		(418	)		(208	)
Charge associated with future ash pond and landfill closure costs		—			81
Net losses (gains) on nuclear decommissioning trust funds and other investments								117			(371	)
Revision to future ash pond and landfill closure costs		(113	)		—			—			(113	)
Other adjustments		(9	)		—			4			4
Changes in:
Accounts receivable		354			129			396			492
Inventories		(106	)		(37	)		7			(14	)
Deferred fuel and purchased gas costs, net		158			(226	)		237			120
Prepayments		31			(81	)		(193	)		22
Accounts payable		(446	)		(167	)		(191	)		(446	)
Accrued interest, payroll and taxes		(123	)		(14	)		(313	)		(264	)
Customer deposits		(94	)		7			(7	)		(85	)
Margin deposit assets and liabilities		54			(5	)		19			113
Net realized and unrealized changes related to derivative activities		1			101
Pension and other postretirement benefits		(107	)		(79	)
Other operating assets and liabilities		(468	)		111			(447	)		(479	)
Net cash provided by operating activities		3,709			3,711			3,136			2,313
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(3,407	)		(3,111	)		(2,915	)		(2,112	)
Cash and restricted cash acquired in the SCANA Combination		389			—			—			389
Acquisition of solar development projects		(183	)		(108	)		(187	)		(152	)
Proceeds from sales of securities		1,311			1,301			1,660			882
Purchases of securities		(1,330	)		(1,364	)		(1,710	)		(888	)
Proceeds from sales of assets and equity method investments		211			200			—			196
Contributions to equity method affiliates		(187	)		(282	)		(39	)		(132	)
Acquisition of equity method investments								(178	)		—
Other		36			(5	)		35			(16	)
Net cash used in investing activities		(3,160	)		(3,369	)		(3,334	)		(1,833	)
Financing Activities
Issuance (repayment) of short-term debt, net		1,913			(363	)		(525	)		2,040
Issuance of short-term notes		3,000			1,450			1,125			—
Repayment of short-term notes		—			(1,450	)		(625	)		—
Credit facility borrowings		—			73
Supplemental 364-Day credit facility borrowings								225			—
Repayment of credit facility borrowings		(113	)		—			—			(113	)
Issuance of long-term debt		2,298			4,400			4,355			798
Repayment of long-term debt, including redemption premiums		(8,595	)		(3,154	)		(2,210	)		(3,378	)
Issuance of 2019 Equity Units		1,582			—			—			1,582
Issuance of common stock		1,802			737			148			325
Common dividend payments		(2,224	)		(1,635	)		(1,577	)		(1,469	)
Other		(163	)		(198	)		(245	)		(96	)
Net cash used in financing activities		(500	)		(140	)
Net cash provided by (used in) financing activities								671			(311	)
Increase in cash, restricted cash and equivalents		49			202			473			169
Cash, restricted cash and equivalents at beginning of period		391			185			269			391
Cash, restricted cash and equivalents at end of period	$	440		$	387		$	742		$	560
Supplemental Cash Flow Information
Significant noncash investing and financing activities:^(1)(2)(3)
Significant noncash investing and financing activities:⁽¹⁾⁽²⁾
Accrued capital expenditures	$	378		$	197		$	346		$	311
Leases⁽⁴⁾		102			—
Leases⁽³⁾								35			24

(1)	~~See Note 2 for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements.~~

~~(2)~~

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

~~(3)~~(2)

See Note 1716 for noncash financing activities related to derivative restructuring, the acquisition of the public interest in Dominion Energy Midstream ~~the remarketing of RSNs~~ and the issuance of stock purchase contracts associated with the 2019 Equity Units.

~~(4)~~

~~Includes $98 million~~ 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 ~~financing leases and $4 million of operating leases.~~RSNs.

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

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 September 30,					Nine Months Ended September 30,				Three Months Ended June 30,					Six Months Ended June 30,
	2019			2018		2019		2018		2020			2019		2020			2019
(millions)
Operating Revenue⁽¹⁾	$	2,264		$	2,232	$	6,167	$	5,809	$	1,805		$	1,938	$	3,735		$	3,903
Operating Expenses
Electric fuel and other energy-related purchases⁽¹⁾		559			648		1,691		1,747		366			536		858			1,132
Purchased (excess) electric capacity		(1	)		50		45		87		(8	)		13		(17	)		46
Other operations and maintenance:
Affiliated suppliers		74			72		287		229		80			127		167			213
Other		379			332		1,010		1,013		296			438		627			631
Depreciation and amortization		313			295		916		839		307			299		618			603
Other taxes		82			79		257		241		85			90		172			175
Impairment of assets and other charges		38			—		781		—		44			197		808			743
Total operating expenses		1,444			1,476		4,987		4,156		1,170			1,700		3,233			3,543
Income from operations		820			756		1,180		1,653		635			238		502			360
Other income		15			25		68		49		52			16		—			53
Interest and related charges⁽¹⁾		138			130		408		388		137			135		263			270
Income before income tax expense		697			651		840		1,314		550			119		239			143
Income tax expense		95			131		118		271		60			19		29			23
Net Income	$	602		$	520	$	722	$	1,043	$	490		$	100	$	210		$	120

(1)	See Note 2019 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 September 30,					Nine Months Ended September 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018		2019			2018			2020			2019			2020			2019
(millions)
Net income	$	602		$	520	$	722		$	1,043		$	490		$	100		$	210		$	120
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		(16	)		3		(34	)		10			1			(11	)		(44	)		(18	)
Changes in unrealized net gains (losses) on nuclear decommissioning trust funds⁽²⁾		1			—		5			(2	)		6			2			4			4
Amounts reclassified to net income:
Net derivative losses-hedging activities⁽³⁾		—			—		1			—
Net realized gains on nuclear decommissioning trust funds⁽⁴⁾		—			—		(1	)		—
Amounts reclassified to net income (loss):
Net derivative (gains) losses-hedging activities⁽³⁾													—			1			—			1
Net realized (gains) losses on nuclear decommissioning trust funds⁽⁴⁾													(2	)		(1	)		(1	)		(1	)
Total other comprehensive income (loss)		(15	)		3		(29	)		8			5			(9	)		(41	)		(14	)
Comprehensive income	$	587		$	523	$	693		$	1,051		$	495		$	91		$	169		$	106

(1)

Net of $5$(1) million and ~~$(1)~~$4 million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and net of ~~$11~~$15 million and ~~$(3)~~$6 million tax for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively.

(2)	Net of $(1) million and $— million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and net of ~~$(2)~~$(1) million and $1$(1) million tax for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, ~~and 2018,~~ respectively.

(3)	Net of $—$(1) million and $ — million tax for ~~both~~ the three ~~and nine~~ months ended ~~September~~June 30, 2020 and 2019, respectively, and ~~2018.~~net of $ (1) million and $ — million tax for the six months ended June 30, 2020 and 2019, respectively.

(4)	Net of $1$2 million and $—$ — million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and net of $1 million and $—$ — million tax for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, ~~and 2018,~~ respectively.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2019			December 31, 2018⁽¹⁾			June 30, 2020			December 31, 2019⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	29		$	29		$	37		$	17
Customer receivables (less allowance for doubtful accounts of $9 at both dates)		1,177			999
Other receivables (less allowance for doubtful accounts of $2 and $3)		51			76
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		8			101			2			27
Inventories (average cost method)		850			837			874			873
Regulatory assets								197			433
Other⁽²⁾		530			529			64			57
Total current assets		2,645			2,571			2,452			2,676
Investments
Nuclear decommissioning trust funds		2,738			2,369			2,782			2,881
Other		3			3			3			3
Total investments		2,741			2,372			2,785			2,884
Property, Plant and Equipment
Property, plant and equipment		46,438			44,524			45,273			47,038
Accumulated depreciation and amortization		(14,036	)		(14,003	)		(13,774	)		(14,156	)
Total property, plant and equipment, net		32,402			30,521			31,499			32,882
Deferred Charges and Other Assets
Regulatory assets		1,917			737			3,780			1,863
Operating lease assets		184			—
Other⁽²⁾		876			679			1,524			1,123
Total deferred charges and other assets		2,977			1,416			5,304			2,986
Total assets	$	40,765		$	36,880		$	42,040		$	41,428

(1)	Virginia Power’s Consolidated Balance Sheet at December 31, ~~2018~~2019 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 2019 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)

	September 30, 2019			December 31, 2018⁽¹⁾			June 30, 2020			December 31, 2019⁽¹⁾
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	3		$	350		$	7		$	4
Short-term debt		685			314			—			243
Accounts payable		286			339			305			334
Payables to affiliates		138			209			406			210
Affiliated current borrowings		9			224			340			107
Accrued interest, payroll and taxes		321			248			276			253
Asset retirement obligations								91			340
Regulatory liabilities								296			167
Derivative liabilities⁽²⁾		165			25			478			243
Regulatory liabilities		180			299
Other		867			807			598			571
Total current liabilities		2,654			2,815			2,797			2,472
Long-Term Debt		11,792			11,321
Long-term debt								12,328			12,325
Finance leases								30			16
Total long-term debt								12,358			12,341
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,911			3,017			2,739			2,962
Asset retirement obligations		3,418			1,200			3,548			3,241
Regulatory liabilities		4,978			4,647			4,954			5,074
Operating lease liabilities		152			—
Other⁽²⁾		1,310			833			1,700			1,349
Total deferred credits and other liabilities		12,769			9,697			12,941			12,626
Total liabilities		27,215			23,833			28,096			27,439
Commitments and Contingencies (see Note 18)
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		6,740			6,208			7,163			7,167
Accumulated other comprehensive loss		(41	)		(12	)		(70	)		(29	)
Total common shareholder’s equity		13,550			13,047			13,944			13,989
Total liabilities and shareholder’s equity	$	40,765		$	36,880		$	42,040		$	41,428

(1)	Virginia Power’s Consolidated Balance Sheet at December 31, ~~2018~~2019 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 2019 for amounts attributable to affiliates.

(3)	500,000 shares authorized; 274,723 shares outstanding at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018.~~2019.

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															Common Stock
	Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total			Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total
(millions, except for shares)	(thousands)															(thousands)
June 30, 2018		275	$	5,738	$	1,113	$	5,655		$	(9	)	$	12,497
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								520						520									490						490
Dividends								(104	)					(104	)								(107	)					(107	)
Other comprehensive income, net of tax											3			3												5			5
Other								1						1
September 30, 2018		275	$	5,738	$	1,113	$	6,072		$	(6	)	$	12,917

June 30, 2019		275	$	5,738	$	1,113	$	6,139		$	(26	)	$	12,964
Net income								602						602
Other comprehensive loss, net of tax											(15	)		(15	)
Other								(1	)					(1	)
September 30, 2019		275	$	5,738	$	1,113	$	6,740		$	(41	)	$	13,550
June 30, 2020																	275	$	5,738	$	1,113	$	7,163		$	(70	)	$	13,944

YEAR-TO-DATE

	Common Stock															Common Stock
	Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total			Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total
(millions, except for shares)	(thousands)															(thousands)
December 31, 2017		275	$	5,738	$	1,113	$	5,311		$	62		$	12,224
Cumulative-effect of changes in accounting principles								79			(76	)		3
Net income								1,043						1,043
Dividends								(361	)					(361	)
Other comprehensive income, net of tax											8			8
September 30, 2018		275	$	5,738	$	1,113	$	6,072		$	(6	)	$	12,917

December 31, 2018		275	$	5,738	$	1,113	$	6,208		$	(12	)	$	13,047			275	$	5,738	$	1,113	$	6,208		$	(12	)	$	13,047
Net income								722						722									120						120
Dividends								(189	)					(189	)								(189	)					(189	)
Other comprehensive loss, net of tax											(29	)		(29	)											(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	)								1						1
September 30, 2019		275	$	5,738	$	1,113	$	6,740		$	(41	)	$	13,550
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)

Nine Months Ended September 30,

2019

2018

(millions)

Operating Activities

Net income

$
722

$
1,043

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

Depreciation and amortization (including nuclear fuel)

1,045

974

Deferred income taxes and investment tax credits

(141
)

175

Charge associated with future ash pond and landfill closure costs

—

81

Revision to future ash pond and landfill closure costs

(113
)

—

Impairment of assets and other charges

646

—

Provision for rate credits to customers

—

77

Charge related to a voluntary retirement program

138

—

Other adjustments

(60
)

(48
)
Changes in:

Accounts receivable

(154
)

(113
)
Affiliated receivables and payables

21

(8
)
Inventories

(34
)

40

Prepayments

(4
)

(1
)
Deferred fuel expenses, net

232

(273
)
Accounts payable

(38
)

(28
)
Accrued interest, payroll and taxes

73

50

Net realized and unrealized changes related to derivative activities

18

69

Asset retirement obligations

33

(29
)
Other operating assets and liabilities

(316
)

197

Net cash provided by operating activities

2,068

2,206

Investing Activities

Plant construction and other property additions

(1,816
)

(1,696
)
Purchases of nuclear fuel

(96
)

(82
)
Acquisition of solar development projects

(169
)

(98
)
Proceeds from sales of securities

677

651

Purchases of securities

(717
)

(681
)
Other

(18
)

(47
)
Net cash used in investing activities

(2,139
)

(1,953
)
Financing Activities

Issuance of short-term debt, net

371

392

Repayment of affiliated current borrowings, net

(215
)

(18
)
Issuance of long-term debt

698

700

Repayment of long-term debt

(590
)

(951
)
Common dividend payments to parent

(189
)

(361
)
Other

(5
)

(7
)
Net cash provided by (used in) financing activities

70

(245
)
Increase (decrease) in cash, restricted cash and equivalents

(1
)

8

Cash, restricted cash and equivalents at beginning of period

38

24

Cash, restricted cash and equivalents at end of period

$
37

$
32

Supplemental Cash Flow Information

Significant noncash investing activities:⁽¹⁾

Accrued capital expenditures

$
231

$
96

Financing leases

13

—

~~(1)~~

~~See Note 2 for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements.~~

Six Months Ended June 30,	2020			2019
(millions)
Operating Activities
Net income	$	210		$	120
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		702			690
Deferred income taxes and investment tax credits		(220	)		(43	)
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
Other adjustments		2			(51	)
Changes in:
Accounts receivable		1			68
Affiliated receivables and payables		220			(179	)
Inventories		(1	)		(30	)
Prepayments		—			(4	)
Deferred fuel expenses, net		136			153
Accounts payable		(9	)		(35	)
Accrued interest, payroll and taxes		18			14
Net realized and unrealized changes related to derivative activities		(20	)		17
Other operating assets and liabilities		47			(331	)
Net cash provided by operating activities		1,892			1,074
Investing Activities
Plant construction and other property additions		(1,474	)		(1,079	)
Purchases of nuclear fuel		(154	)		(67	)
Acquisition of solar development projects		(19	)		(150	)
Proceeds from sales of securities		530			447
Purchases of securities		(549	)		(478	)
Other		18			(11	)
Net cash used in investing activities		(1,648	)		(1,338	)
Financing Activities
(Repayment) issuance of short-term debt, net		(243	)		986
Issuance (repayment) of affiliated current borrowings, net		233			(153	)
Issuance of long-term debt		105			198
Repayment of long-term debt		(105	)		(589	)
Common dividend payments to parent		(215	)		(189	)
Other		(3	)		(2	)
Net cash provided by (used in) financing activities		(228	)		251
Increase (decrease) in cash, restricted cash and equivalents		16			(13	)
Cash, restricted cash and equivalents at beginning of period		24			38
Cash, restricted cash and equivalents at end of period	$	40		$	25
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	239		$	193
Financing leases		20			9

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 September 30,						Nine Months Ended September 30,						Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Operating Revenue⁽¹⁾	$	392		$	423		$	1,303		$	1,408		$	510		$	530		$	1,066		$	1,096
Operating Expenses
Purchased (excess) gas⁽¹⁾		5			(7	)		49			22			—			(3	)		8			9
Other energy-related purchases		17			26			62			88			1			1			1			1
Other operations and maintenance:
Affiliated suppliers		22			21			95			70			39			54			79			93
Other		137			159			452			502			111			156			236			293
Depreciation and amortization		64			61			188			173			94			92			187			182
Other taxes		47			45			162			152			35			38			77			78
Impairment of assets and other charges		—			1			13			127			482			13			482			13
Gains on sales of assets		(7	)		(65	)		(7	)		(116	)
Total operating expenses		285			241			1,014			1,018			762			351			1,070			669
Income from operations		107			182			289			390
Earnings from equity method investee		3			4			13			18
Other income		35			34			103			99
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⁾		26			28			77			79			50			86			108			173
Income from operations before income taxes		119			192			328			428
Income tax expense		27			56			73			111
Net Income	$	92		$	136		$	255		$	317
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 2019 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 September 30,

Nine Months Ended September 30,

2019

2018

2019

2018

(millions)

Net income

$
92

$
136

$
255

$
317

Other comprehensive income (loss), net of taxes:

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

(36
)

3

(87
)

(4
)
Changes in unrecognized pension and other
   postretirement benefit costs⁽²⁾

(1
)

—

28

—

Amounts reclassified to net income:

Net derivative losses-hedging activities⁽³⁾

9

5

11

16

Net pension and other postretirement benefit
   costs⁽⁴⁾

1

2

4

4

Total other comprehensive income (loss)

(27
)

10

(44
)

16

Comprehensive income

$
65

$
146

$
211

$
333

	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 ~~$13~~$(1) million and ~~$(1)~~$8 million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and ~~net of $30~~$31 million and $2$17 million tax for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, ~~and 2018,~~ respectively.

(2)	Net of $—$ — million and $(11) million tax for ~~both~~ the three months ended ~~September~~June 30, 2020 and 2019, respectively, and ~~2018, and net of $(11)~~$ — million and $—$(11) million tax for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively.

(3)

Net of ~~$(3)~~$ — million and ~~$(2)~~$— million tax for the three months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively, and ~~net of $(4)~~$(2) million and ~~$(6)~~$ — million tax for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively.

(4)	Net of $—$ — million and $ — million tax for ~~both~~ the three months ended ~~September~~June 30, 2020 and 2019, respectively, and ~~2018,~~$(1) million and ~~net of~~ $(1) million tax for ~~both~~ the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, ~~and 2018.~~respectively.

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2019			December 31, 2018⁽¹⁾			June 30, 2020			December 31, 2019⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	11		$	10		$	53		$	27
Customer receivables (less allowance for doubtful accounts of less than $1 at both dates)⁽²⁾		212			309
Other receivables (less allowance for doubtful accounts of $1 and $2)⁽²⁾		21			17
Customer receivables (less allowance for doubtful accounts of $5 and $2)								151			173
Other receivables⁽²⁾								12			26
Affiliated receivables		40			10			77			362
Affiliated notes receivable								263			—
Inventories		105			65			130			122
Regulatory assets		42			29
Prepayments								43			73
Gas imbalances⁽²⁾		29			162			25			52
Other⁽²⁾		77			145
Other								23			23
Total current assets		537			747			777			858
Investments		81			93
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		11,780			11,238			14,899			15,166
Accumulated depreciation and amortization		(3,114	)		(2,971	)		(3,695	)		(3,538	)
Total property, plant and equipment, net		8,666			8,267			11,204			11,628
Deferred Charges and Other Assets
Pension and other postretirement benefit assets⁽²⁾		2,016			1,775
Operating lease assets		56			—
Goodwill								1,471			1,471
Other⁽²⁾		1,390			1,469			1,107			1,078
Total deferred charges and other assets		3,462			3,244			2,578			2,549
Total assets	$	12,746		$	12,351		$	17,141		$	18,784

(1)	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, ~~2018~~2019 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 2019 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)

	September 30, 2019			December 31, 2018⁽¹⁾			June 30, 2020			December 31, 2019⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	452		$	449		$	1,200		$	700
Short-term debt		280			10			—			62
Accounts payable		87			196			52			59
Payables to affiliates		23			65			159			82
Affiliated current borrowings		160			218			314			260
Other⁽²⁾		460			463			382			289
Total current liabilities		1,462			1,401			2,107			1,452
Long-Term Debt		3,606			3,609
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		1,509			1,465			1,156			1,288
Regulatory liabilities		1,299			1,285
Operating lease liabilities		44			—
Other		218			194			1,093			989
Total deferred credits and other liabilities		3,070			2,944			2,249			2,277
Total liabilities		8,138			7,954			8,685			8,555
Commitments and Contingencies (see Note 18)
Commitments and Contingencies (see Note 17)
Equity
Membership interests		4,821			4,566			7,352			9,031
Accumulated other comprehensive loss		(213	)		(169	)		(271	)		(187	)
Total members' equity								7,081			8,844
Noncontrolling interests								1,375			1,385
Total equity		4,608			4,397			8,456			10,229
Total liabilities and equity	$	12,746		$	12,351		$	17,141		$	18,784

(1)	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, ~~2018~~2019 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 2019 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

	Membership Interests		AOCI			Total			Predecessor Equity			Membership Interests			AOCI			Total Members' Equity			Noncontrolling Interests			Total
(millions)
June 30, 2018	$	4,446	$	(118	)	$	4,328
March 31, 2019									$	2,938		$	4,682		$	(191	)	$	7,429		$	1,432		$	8,861
Net income		136					136			72			47						119			30			149
Dividends and distributions										(153	)								(153	)		(36	)		(189	)
Other comprehensive income, net of tax				10			10									5			5						5
September 30, 2018	$	4,582	$	(108	)	$	4,474
Other										2									2						2
June 30, 2019									$	2,859		$	4,729		$	(186	)	$	7,402		$	1,426		$	8,828

June 30, 2019	$	4,729	$	(186	)	$	4,543
Net income		92					92
Other comprehensive loss, net of tax				(27	)		(27	)
September 30, 2019	$	4,821	$	(213	)	$	4,608
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

Membership
Interests

AOCI

Total

(millions)

December 31, 2017

$
4,261

$
(98
)

$
4,163

Cumulative-effect of changes in accounting principles

29

(26
)

3

Net income

317

317

Distributions

(25
)

(25
)
Other comprehensive income, net of tax

16

16

September 30, 2018

$
4,582

$
(108
)

$
4,474

December 31, 2018

$
4,566

$
(169
)

$
4,397

Net income

255

255

Other comprehensive loss, net of tax

(44
)

(44
)
September 30, 2019

$
4,821

$
(213
)

$
4,608

	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 ~~Statement~~s.Statements.

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Nine Months Ended September 30,	2019			2018
Six Months Ended June 30,							2020			2019
(millions)
Operating Activities
Net income	$	255		$	317
Net income including noncontrolling interests							$	36		$	375
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		188			173			187			227
Deferred income taxes and investment tax credits		40			86			(97	)		39
Charge related to a voluntary retirement program		39			—			—			73
Impairment of assets and other charges		13			129			482			13
Gains on sales of assets		(7	)		(109	)
Other adjustments		6			5			(1	)		15
Changes in:
Accounts receivable		93			98			37			88
Affiliated receivables and payables		(72	)		(25	)		362			(48	)
Inventories		(40	)		(25	)		(8	)		(31	)
Deferred purchased gas costs, net		5			8
Prepayments		49			46			30			59
Accounts payable		(106	)		(110	)		6			(105	)
Accrued interest, payroll and taxes		(49	)		(46	)		(16	)		(55	)
Customer deposits								(1	)		(81	)
Pension and other postretirement benefits		(107	)		(108	)		(35	)		(64	)
Other operating assets and liabilities		(60	)		23			26			(45	)
Net cash provided by operating activities		247			462			1,008			460
Investing Activities
Plant construction and other property additions		(462	)		(550	)		(147	)		(341	)
Proceeds from assignments of shale development rights		—			109
Repayment of loans by affiliates								1,165			—
Advances to affiliates								(263	)		—
Other		(13	)		(14	)		(4	)		(12	)
Net cash used in investing activities		(475	)		(455	)
Net cash provided by (used in) investing activities								751			(353	)
Financing Activities
Issuance (repayment) of short-term debt, net		270			(488	)		(62	)		240
Issuance of long-term debt		—			500
Issuance (repayment) of affiliated current borrowings, net		(58	)		6			54			(11	)
Distribution payments to parent		—			(25	)
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		—			(4	)		(1	)		(1	)
Net cash provided by (used in) financing activities		212			(11	)
Decrease in cash, restricted cash and equivalents		(16	)		(4	)
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		34			30			39			198
Cash, restricted cash and equivalents at end of period	$	18		$	26		$	64		$	207
Supplemental Cash Flow Information
Significant noncash investing activities:⁽¹⁾
Significant noncash investing activities:
Accrued capital expenditures	$	35		$	43		$	24		$	43
Financing leases		10			—			1			6

~~(1)~~

~~See Note 2 for noncash investing and financing activities related to the adoption of a new accounting standard for leasing arrangements.~~

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 of energy. Dominion Energy’s operations are conducted through various subsidiaries, including Virginia Power and Dominion Energy Gas. 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 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 ~~a regulated~~FERC-regulated interstate natural gas transmission pipeline and underground storage system in the Northeast, mid-Atlantic and Midwest states, regulated gas transportation and distribution operations in Ohio, and gas gathering and processing activities primarily in West Virginia, Ohio and Pennsylvania. In addition, other Dominion Energy subsidiaries provide merchant generation, LNG terminalling services, natural gas transmission and distribution services primarilysystems in the eastern and Rocky Mountain regions of the U.S. ~~The SCANA Combination was completed~~, as well as the Cove Point LNG Facility. In addition, Dominion Energy Gas owns a 50% noncontrolling interest in ~~January 2019.~~both Iroquois and White River Hub. See Note 3 for ~~a description~~additional information on the Dominion Energy Gas Restructuring. In July 2020, Dominion Energy entered an agreement to sell substantially all of its gas transmission and storage operations, ~~acquired in the SCANA Combination.~~including Dominion Energy Gas, to BHE. See Note 3 for additional information.

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, ~~2018.~~2019.

In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position at ~~September~~June 30, ~~2019,~~2020, their results of operations and changes in equity for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018~~2019 and their cash flows for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018.~~2019. 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 December 31, 2018, Dominion Energy owned the general partner, 60.9% of the common units and 37.5% of the convertible preferred interests in Dominion Energy Midstream, with the public’s ownership interest reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. In January 2019, Dominion Energy acquired all outstanding partnership interests not owned by Dominion Energy and Dominion Energy Midstream became a wholly-owned subsidiary of Dominion Energy. Also, at SeptemberJune 30, ~~2019,~~2020, Dominion Energy owns 50% of the ~~units~~voting interests in ~~and consolidates~~ Four Brothers and Three ~~Cedars.~~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, ~~as well as~~ Terra Nova Renewable Partners’ 33% interest in certain Dominion Energy merchant solar projects, isBrookfield’s 25% interest in Cove Point (effective December 2019) and the non-Dominion Energy held interest in Dominion Energy Midstream (through January 2019) are reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. Terra Nova Renewable Partners has a future option to buy all or a portion of Dominion Energy’s remaining 67% ownership in ~~the~~certain merchant projects upon the occurrence of certain events, none of which ~~had occurred at September 30, 2019 nor~~ are expected to occur in the ~~remainder of 2019.~~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.

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’ ~~2018~~2019 Consolidated Financial Statements and Notes have been reclassified to conform to the ~~2019~~2020 presentation for comparative purposes; however, such reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows.

Amounts disclosed for Dominion Energy are inclusive of Virginia Power 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, ~~2018,~~2019, with the exception of the items described below.

Cash, Restricted Cash and Equivalents

The following table provides a reconciliation of the total cash, restricted cash and equivalents reported within the Companies’ Consolidated Balance Sheets to the corresponding amounts reported within the Companies’ Consolidated Statements of Cash Flows for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018:~~2019:

	Cash, Restricted Cash and Equivalents at End of Period				Cash, Restricted Cash and Equivalents at Beginning of Period				Cash, Restricted Cash and Equivalents at End of Period				Cash, Restricted Cash and Equivalents at Beginning of Period
	September 30, 2019		September 30, 2018		December 31, 2018		December 31, 2017		June 30, 2020		June 30, 2019		December 31, 2019		December 31, 2018
(millions)
Dominion Energy
Cash and cash equivalents	$	378	$	310	$	268	$	120	$	675	$	382	$	166	$	268
Restricted cash and equivalents⁽¹⁾		62		77		123		65		67		178		103		123
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	440	$	387	$	391	$	185	$	742	$	560	$	269	$	391
Virginia Power
Cash and cash equivalents	$	29	$	22	$	29	$	14	$	37	$	17	$	17	$	29
Restricted cash and equivalents⁽¹⁾		8		10		9		10		3		8		7		9
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	37	$	32	$	38	$	24	$	40	$	25	$	24	$	38
Dominion Energy Gas
Cash and cash equivalents	$	11	$	4	$	10	$	4
Cash and cash equivalents⁽²⁾									$	53	$	195	$	27	$	108
Restricted cash and equivalents ⁽¹⁾		7		22		24		26		11		12		12		90
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	18	$	26	$	34	$	30	$	64	$	207	$	39	$	198

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

(2)	At June 30, 2019 and December 31, 2018, Dominion Energy Gas had $12 million and $9 million of cash and cash equivalents included in current assets of discontinued operations, respectively.

Property, Plant and Equipment

In January 2019, Virginia Power committed to a plan to retire certain automated ~~meter~~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, ~~2018.~~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, ~~2018.~~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 ~~September 2019, Dominion Energy and~~March 2020, Virginia Power ~~abandoned~~committed to retire certain ~~property, plant~~coal- and ~~equipment~~oil-fired generating units before the end of ~~its~~their useful ~~life.~~ 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, ~~Dominion Energy recorded a charge of $26 million ($19 million after-tax) and~~ Virginia Power recorded a charge of ~~$17~~$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.

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)~~, included~~ 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.

In the second quarter of 2020, DESC completed a nuclear decommissioning cost study related to Summer. 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 million ($359 million after-tax) in impairment of assets and other charges in their Consolidated Statements of Income for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019.~~

~~Leases~~

~~The Companies lease certain assets including vehicles, real estate, office equipment and other operational assets under both operating and finance leases. For~~2020 associated with the ~~Companies’ operating leases, rent expense is recognized on~~probable abandonment of a ~~straight-line basis over the term~~significant portion of the ~~lease agreement, subject~~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 ~~regulatory framework. Rent expense~~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 ~~operating leases, short-term leases~~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 ~~variable leases is primarily~~ 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 ~~operations and maintenance expense~~investments in the ~~Companies’~~ Consolidated ~~Statements of Income. Rent expense associated~~Balance Sheets at fair value with ~~finance leases results~~net realized and unrealized gains and losses included in other income in the ~~separate presentation of interest expense on the lease liability and amortization expense of the related right-of-use asset in the Companies’~~ Consolidated Statements of Income.

~~Certain~~

• Debt securities classified as available-for-sale securities include all other debt securities, primarily comprised of the Companies’ leases include one or more options to renew, with renewal terms that can extend the lease from one to 70 years. The exercise of renewal options is solely at the Companies’ discretion and is includedsecurities held in the ~~lease term if the option is reasonably certain to be exercised. A right-of-use asset and corresponding lease liability for leases with original lease terms of one year or less~~nuclear decommissioning trusts. These investments are ~~not included~~reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance ~~Sheets, unless such leases contain renewal options that~~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 ~~Companies are reasonably certain will be exercised. Additionally, certain~~cost basis of the ~~Companies’ leases contain escalation clauses whereby payments are adjusted for consumer price or other indices or contain fixed dollar or percentage increases. The Companies also have leases~~security is based on the specific identification method.

Equity securities with ~~variable payments based upon usage of, or revenues~~readily determinable fair values include securities held by Dominion Energy in rabbi trusts associated with ~~the leased assets.~~

~~The determination of the discount rate utilized has a significant impact on the calculation of the present value of the lease liability included~~certain deferred compensation plans and securities held by Dominion Energy and Virginia Power in the ~~Companies’~~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 ~~the Companies’ fleet of leased vehicles, the discount rate is equal to the prevailing borrowing rate earned by the lessor. For the Companies’ remaining leased assets, the discount rate implicit~~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 ~~lease is generally unable to be determined from a lessee perspective. As such,~~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 ~~use internally-developed incremental borrowing rates as a discount rate~~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 ~~calculation~~net assets of the present value of the lease liability. The incremental borrowing rates are determined based on an analysis of the Companies’ publicly available unsecured borrowing rates, adjusted for a collateral discount, over various lengths of time that most closely correspond to the Companies’ lease maturities.

In addition, Dominion Energy acts as lessor under certain power purchase agreements in which the counterparty or counterparties purchase substantially all of the output of certain solar facilities. These leases are considered operating in nature. For such leasing arrangements, rental revenue and an associated accounts receivable are recorded when the monthly output of the solar facility is determined. Depreciation on these solar facilities is computed on a straight-line basis over an estimated useful life of 30 years.

~~New Accounting Standards~~

~~Leases~~

In February 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of leasing arrangements. The update requires that a liability and corresponding right-of-use asset are recorded on the balance sheet for all leases, including those leases classified as operating leases, while also refining the definition of a lease. In addition, lessees are required to disclose key information about the amount, timing and uncertainty of cash flows arising from leasing arrangements. Lessor accounting remains largely unchanged.

The guidance became effective for the Companies’ interim and annual reporting periods beginning January 1, 2019. The Companies adopted this revised accounting guidance using a modified retrospective approach, which requires lessees and lessors to recognize and measure leasesinvestee at the date of ~~adoption. Under this approach,~~investment and other adjustments required by the ~~Companies utilized~~equity method.

• Cost method investments when Dominion Energy and Virginia Power do not have the ~~transition practical expedient~~ability to ~~maintain historical presentation~~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 ~~periods before January 1, 2019.~~ identical or similar investments of the same issuer.

Other-Than-Temporary Impairment

The Companies ~~also applied~~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 ~~other practical expedients, which required no reassessment~~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 ~~existing contracts are~~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 ~~contain leases, no reassessment~~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 ~~lease classification for existing leases~~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 ~~no reassessment of existing or expired land easements that were not previously accounted for as leases. In connection~~Virginia Power record the credit loss in earnings with the ~~adoption~~remaining non-credit portion of ~~this revised accounting guidance, Dominion Energy, Virginia Power~~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 Dominion Energy Gas recorded $504 million, $209 million and $64 million, respectively, of offsetting right-of-use assets and liabilities for operating leases in effect at the adoption date. See Note 15 for additional information.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 ~~markets~~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, ~~2018 and Notes 13, 17 and 18~~2019 for more information on the SCANA Combination, including merger approval and conditions, information on assets acquired and liabilities ~~acquired, significant financing transactions, regulatory matters~~assumed and ~~proceedings,~~purchase price allocation. In addition, see Note 17 for a discussion of certain legal proceedings ~~and commitments and contingencies.~~

~~Merger Approval and Conditions~~

~~Merger Approval~~

~~The~~involving Dominion Energy, SCANA Combination required approval of SCANA’s shareholders, FERC, the North Carolina Commission, the South Carolina Commission, the Georgia Public Service Commission and the NRC and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. All such approvals were received prioror DESC relating to events occurring before closing of the SCANA Combination.

~~Various parties filed petitions for rehearing or reconsideration of the SCANA Merger Approval Order.~~ In January 2019, the South Carolina Commission issued an order (1) granting the request of various parties and finding that DESC was imprudent in its actions by not disclosing material information to the South Carolina Office of Regulatory Staff and the South Carolina Commissionaccordance with ~~regard to costs incurred subsequent to March 2015 and (2) denying the petitions for rehearing or consideration as to other issues raised in the various petitions. The deadline to appeal~~ the SCANA Merger Approval Order, ~~and the order on rehearing expired in April 2019, and no party has sought appeal.~~

~~Refunds~~Dominion Energy incurred certain charges to ~~Customers~~

~~As a condition to the SCANA Merger Approval Order, DESC will provide refunds and restitution of $2.0 billion over 20 years with capital support from Dominion Energy.~~

~~In September and October 2017, DESC received proceeds totaling $1.1 billion in full satisfaction of~~ its share of a settlement agreement among DESC, Santee Cooper and Toshiba Corporation in connection with Westinghouse and WECTEC, both wholly-owned subsidiaries of Toshiba Corporation and responsible for the engineering and construction of the NND Project, filing for bankruptcy. The purchase price allocation below includes a previously established regulatory liability at DESC totaling $1.1 billion, of which $67 million was considered current, associated with the monetization of the bankruptcy settlement with Toshiba Corporation. In accordance with the terms of the SCANA Merger Approval Order, this regulatory liability, net of amounts that may be required to satisfy any liens against NND Project property, totaling $1.0 billion will be refunded to DESC electric service customers over a 20-year period ending in 2039.

Additionally, in the first quarter of 2019, DESC recorded a reduction in operating revenue and a corresponding regulatory liability of $1.0 billion, of which $137 million was considered current, 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. As a result, Dominion Energy’s Consolidated ~~Statement~~Statements of Income for the ~~nine months ended September 30, 2019 includes a $756 million after-tax charge.~~

~~NND Project~~

As a condition to the SCANA Merger Approval Order, DESC committed to excluding from rate recovery $2.4 billion of costs related to the NND Project and $180 million of costs associated with the purchase of the Columbia Energy Center power station. Regulatory assets included in SCANA’s historical balance sheet at December 31, 2018 reflected these disallowances.

The remaining regulatory asset associated with the NND Project of $2.8 billion, of which $138 million was considered current, will be collected over a 20-year period, including a return on investment. In January 2019, DESC filed the NND Project rider in accordance with the terms of the SCANA Merger Approval Order for rates effective in February 2019 for DESC’s retail electric customers. The South Carolina Commission approved this filing in January 2019.

~~Other Terms and Conditions~~following:

•

In the first quarter of 2019, DESC ~~will not file~~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 ~~application~~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 ~~general rate case with the South Carolina Commission with a requested effective date earlier than January 2021;~~

•

~~PSNC will not file an application for a general rate case with the North Carolina Commission with a requested effective date earlier than April 2021;~~$756 million after-tax charge.

•

Dominion Energy ~~has~~ committed to ~~increasing SCANA’s historical level~~forgo recovery of ~~corporate contributions to charities by $1 million per year over the next five years;~~

•

~~Dominion Energy will maintain DESC and PSNC’s headquarters in Cayce, South Carolina and Gastonia, North Carolina, respectively; and~~

•

Dominion Energy will seek to minimize reductions in local employment by allowing some DES employees supporting shared and common services functions and activities to be located in Cayce, South Carolina where it makes economic and practical sense to do so.

~~Purchase Price Allocation~~

SCANA’s assets acquired and liabilities assumed have been measured at estimated fair value at closing and are included in the Southeast Energy operating segment, which was established following the closing of the SCANA Combination. The majority of the operations acquired are subject to the rate setting authority of FERC and the North and South Carolina Commissions and are therefore accounted for pursuant to ASC 980, ~~Regulated Operations~~. The fair values of SCANA’s assets and liabilities subject to rate-setting and cost recovery provisions provide revenues derived from costs, including a return on investment of assets and liabilities included in rate base. As such, the fair values of these assets and liabilities equal their carrying values. Accordingly, neither the assets and liabilities acquired, nor the unaudited pro forma financial information, reflect any adjustments related to these amounts.

The fair value of SCANA’s assets acquired and liabilities assumed that are not subject to the rate-setting provisions discussed above and the fair values of SCANA’s investments accounted for under the equity method have been determined using the income approach and the market approach. The valuation of SCANA’s long-term debt is considered a Level 2 fair value measurement. All other valuations are considered Level 3 fair value measurements due to the use of significant judgmental and unobservable inputs, including projected timing and amount of future cash flows and discount rates reflecting risk inherent in the future market prices.

The excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed is reflected as goodwill. The goodwill reflects the value associated with enhancing Dominion Energy’s portfolio of regulated operations in the growing southeast region of the U.S. The goodwill recognized is not deductible for income tax purposes, and as such, no deferred taxes have been recorded related to goodwill.

The table below shows the preliminary allocation of the purchase price to the assets acquired and liabilities assumed at closing, including adjustments related to income taxes identified during 2019 as discussed in Note 5. The allocation is subject to change during the measurement period as additional information is obtained about the facts and circumstances that existed at closing. Any material adjustments to provisional amounts identified during the measurement period will be recognized and disclosed in the reporting period in which the adjustment amounts are determined. Certain tax-related amounts in the allocation of the purchase price below are preliminary and may change as Dominion Energy completes its analysis and review of applicable tax matters.

Amount

(millions)

Total current assets⁽¹⁾

$
1,782

Investments

224

Property, plant and equipment⁽²⁾

11,006

Goodwill

2,576

Regulatory assets⁽³⁾

3,940

Other deferred charges and other assets, including intangible assets

430

Total Assets

19,958

Total current liabilities

1,515

Long-term debt

6,707

Deferred income taxes

1,114

Regulatory liabilities

2,668

Other deferred credits and other liabilities⁽⁴⁾

1,115

Total Liabilities

13,119

Total purchase price⁽⁵⁾

$
6,839

~~(1)~~

~~Includes $389 million of cash, restricted cash and equivalents, of which $115 million is considered restricted.~~

~~(2)~~

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

~~(3)~~•

~~Includes~~Dominion Energy committed to forgo recovery of $264 million of certain income tax-related regulatory assets associated with the NND ~~Project~~Project. As a result, Dominion Energy’s Consolidated Statement of Income for ~~which Dominion Energy committed to forgo recovery~~the six months ended June 30, 2019 includes a charge of $198 million included in ~~accordance with the SCANA Merger Approval Order. See Note 5 for additional information.~~income tax expense.

~~(4)~~

~~Includes a $379 million pension and other postretirement benefit liability.~~

~~(5)~~

~~Includes stock-based compensation awards with a fair value of $21 million.~~

See Note 3 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018 for a description of assets acquired and liabilities assumed in connection with the SCANA Combination.

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 ~~in the Consolidated Statements of Income~~ was an increase of ~~$979~~$58 million and ~~$97~~a decrease of $102 million for the three months ended ~~September~~June 30, 2020 and 2019, respectively, and an increase of ~~$2.1 billion~~$112 million and a decrease of ~~$1.1~~$1.2 billion for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, ~~respectively.~~respectively, in the Consolidated Statements of Income.

Dominion Energy incurred merger and integration-related costs of ~~$29~~$23 million and ~~$596~~$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 ~~nine~~six months ended ~~September~~June 30, 2019, respectively. These amounts for both the three and ~~nine~~six months ended ~~September~~June 30, 2019 include $4$423 million ~~and $427 million, respectively,~~ for a charge related to a voluntary retirement program. See Note 2120 for additional information. Of the remaining merger and integration-related costs, ~~$25~~$20 million and ~~$160~~$135 million was recorded in other operations and maintenance expense in the Consolidated Statements of Income for the three and ~~nine~~six months ended ~~September~~June 30, 2019, respectively, ~~and less than $1 million~~ and $9 million was recorded in interest and related charges in the Consolidated ~~Statements~~Statement of Income for the ~~three and nine~~six months ended ~~September~~June 30, ~~2019, respectively. During~~2019. There were 0 such charges recorded in interest and related charges for the three ~~and nine~~ months ended ~~September~~June 30, 2018, Dominion Energy incurred merger and integration-related costs of $3 million and $17 million, respectively, recorded primarily in other operations and maintenance expense in the Consolidated Statements of Income.2019. These costs consist of professional fees, ~~the~~ charitable contribution ~~commitment described above,~~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 ~~may change as Dominion Energy finalizes its valuation of certain assets acquired and liabilities assumed at the acquisition date. The unaudited pro forma financial information~~ 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 September 30,				Nine Months Ended September 30,
	2019⁽¹⁾		2018⁽¹⁾		2019⁽¹⁾		2018⁽¹⁾		Three Months Ended June 30, 2019⁽¹⁾		Six Months Ended June 30, 2019⁽¹⁾
(millions, except EPS)
Operating Revenue	$	4,269	$	4,356	$	13,104	$	12,902	$	3,970	$	8,835
Net income attributable to Dominion Energy		1,029		923		1,991		2,054		392		962
Earnings Per Common Share – Basic	$	1.28	$	1.23	$	2.47	$	2.74	$	0.49	$	1.21
Earnings Per Common Share – Diluted	$	1.26	$	1.23	$	2.44	$	2.74	$	0.47	$	1.19

(1)	Amounts include adjustments for non-recurring costs directly related to the SCANA Combination.

~~Expected Sale~~Disposition of ~~Interest~~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

~~In October 2019, Dominion Energy signed an agreement to sell a noncontrolling~~ (consisting of 100% of the general partner interest ~~(consisting of~~and 25% of the total limited ~~partnership~~partner interests). Upon closing, 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 as the assets and obligations of the pension and other postretirement employee benefit plans associated with the operations to ~~Brookfield~~be sold and relating to services provided through closing. The sale will be treated as an asset sale for ~~cash consideration of approximately $2.1 billion, subject to working capital adjustments, which~~tax purposes and is expected to close in the fourth quarter of 2020, contingent on clearance or approval under the Hart-Scott-Rodino Act and from the DOE, and other customary closing and regulatory conditions. Based on the recorded balances at June 30, 2020, Dominion Energy expects to recognize a pre-tax gain of approximately $1 billion upon closing, excluding 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, as held for sale and will report the associated results of operations as discontinued operations starting in the third quarter of 2020. In addition, in the third quarter of 2020, Dominion Energy 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 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 the assets and liabilities of such entities since the applicable inception dates 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% interest 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

Note 4. Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018		2020		2019		2020		2019
(millions)
Dominion Energy
Regulated electric sales:
Residential	$	1,440	$	1,036	$	3,180	$	2,641	$	1,091	$	1,094	$	2,249	$	1,740
Commercial		962		737		2,347		1,897		728		889		1,526		1,385
Industrial		227		143		474		371		176		217		358		247
Government and other retail		244		224		658		647		193		214		412		414
Wholesale		45		30		134		95		29		41		62		89
Nonregulated electric sales		197		322		688		1,022		177		175		409		491
Regulated gas sales:
Residential		121		73		900		553		182		177		730		779
Commercial		52		15		316		152		63		73		254		264
Other		23		3		86		14		16		25		44		63
Nonregulated gas sales		51		42		369		139		33		71		116		318
Regulated gas transportation and storage:
FERC-regulated		248		266		772		800		247		247		528		524
State-regulated		168		138		547		472		182		166		414		379
Nonregulated gas transportation and storage		153		162		501		286		176		174		351		348
Other regulated revenues⁽¹⁾		54		38		180		132		98		82		173		126
Other nonregulated revenues⁽¹⁾⁽²⁾		96		133		305		410		79		101		167		209
Total operating revenue from contracts with customers		4,081		3,362		11,457		9,631		3,470		3,746		7,793		7,376
Other revenues⁽³⁾		188		89		640		374		115		224		288		452
Total operating revenue	$	4,269	$	3,451	$	12,097	$	10,005	$	3,585	$	3,970	$	8,081	$	7,828
Virginia Power
Regulated electric sales:
Residential	$	1,085	$	1,036	$	2,816	$	2,641	$	818	$	808	$	1,714	$	1,731
Commercial		732		737		2,049		1,897		546		681		1,160		1,317
Industrial		121		143		351		371		89		118		186		230
Government and other retail		224		224		625		647		177		197		380		401
Wholesale		31		30		97		95		21		29		45		66
Other regulated revenues⁽¹⁾		36		30		124		95
Other nonregulated revenues⁽²⁾		21		10		54		41
Other regulated revenues										94		62		156		88
Other nonregulated revenues⁽¹⁾⁽²⁾										20		19		33		33
Total operating revenue from contracts with customers		2,250		2,210		6,116		5,787		1,765		1,914		3,674		3,866
Other revenues⁽²⁾⁽³⁾		14		22		51		22		40		24		61		37
Total operating revenue	$	2,264	$	2,232	$	6,167	$	5,809	$	1,805	$	1,938	$	3,735	$	3,903
Dominion Energy Gas
Regulated gas sales:
Residential	$	9	$	12	$	51	$	54
Other		1		—		3		9
Regulated gas sales - wholesale									$	—	$	—	$	2	$	2
Nonregulated gas sales⁽²⁾		2		2		5		5		—		1		1		3
Regulated gas transportation and storage:
FERC-regulated⁽²⁾		180		179		566		561
State-regulated⁽²⁾		139		131		460		450
NGL revenue⁽¹⁾⁽²⁾		31		42		112		146
Regulated gas transportation and storage⁽²⁾										302		306		646		646
Nonregulated gas transportation and storage										175		173		350		348
Management service revenue⁽²⁾		23		50		81		157		29		45		60		88
Other regulated revenues⁽²⁾		4		4		17		16
Other regulated revenues⁽¹⁾										2		3		3		6
Other nonregulated revenues⁽¹⁾⁽²⁾		3		3		7		9		1		1		2		1
Total operating revenue from contracts with customers		392		423		1,302		1,407		509		529		1,064		1,094
Other revenues		—		—		1		1
Other revenues⁽²⁾										1		1		2		2
Total operating revenue	$	392	$	423	$	1,303	$	1,408	$	510	$	530	$	1,066	$	1,096

~~(1)~~1)

Amounts above include ~~$36~~sales which are considered to be goods transferred at a point in time. Such amounts included $19 million and ~~$28~~$— million for the three months ended ~~September~~June 30, ~~2019, $108~~2020, $42 million and ~~$91~~$2 million for the three months ended ~~September~~June 30, ~~2018, $129~~2019, $58 million and ~~$101~~$1 million for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~$170 million~~$93 and ~~$138~~$3 million for the ~~nine~~six months ended ~~September~~June 30, ~~2018~~2019, primarily consisting of NGL sales at Dominion Energy and Dominion Energy Gas, ~~respectively, which are considered to be goods transferred at a point in time. In addition, the~~respectively. Additionally, amounts above include ~~$12 million and $19 million of~~ sales of renewable energy ~~credits at Dominion Energy~~credits. Such amounts included $7 million and $5 million for the three ~~and nine~~ months ended ~~September~~June 30, 2020, $4 million and $2 million for the three months ended June 30, 2019, ~~respectively,~~ $11 million and ~~$14~~$8 million ~~at Virginia Power~~ for the ~~three and nine~~six months ended ~~September~~June 30, 2020 and $7 million and $3 million for the six months ended June 30, 2019, ~~respectively, and $10 million and $11 million~~ at ~~both~~ Dominion Energy and Virginia Power, ~~for the three and nine months ended September 30, 2018, respectively, which are considered to be goods transferred at a point in time.~~respectively.

~~(2)~~2)

See Notes 10 and 2019 for amounts attributable to related parties and affiliates.

~~(3)~~3)

Amounts above include alternative revenue of $9$39 million and ~~$44~~$21 million at Dominion Energy and $9$34 million and ~~$35~~$18 million at Virginia Power for the three ~~and nine~~ months ended ~~September~~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.

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 September 30, 2019	2019		2020		2021		2022		2023		Thereafter		Total
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	$	431	$	1,545	$	1,446	$	1,344	$	1,199	$	13,502	$	19,467	$	823	$	1,567	$	1,475	$	1,315	$	1,190	$	13,095	$	19,465
Virginia Power		5		3		1		—		—		—		9		2		1		—		—		—		—		3
Dominion Energy Gas		168		617		541		443		325		1,902		3,996		899		1,719		1,585		1,402		1,248		13,280		20,133

Contract assets represent an entity’s right to consideration in exchange for goods and services that the entity has transferred to a customer. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy’s contract asset balances were ~~$34~~$25 million and ~~$42~~$28 million, respectively. Dominion Energy Gas’ contract asset balances were ~~$47~~$35 million and ~~$58~~$40 million at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~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 ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy’s contract liability balances were ~~$127~~$109 million and ~~$106~~$123 million, respectively. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Virginia Power’s contract liability balances were ~~$25~~$37 million and ~~$22~~$24 million, respectively. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy Gas’ contract liability balances were ~~$38~~$21 million and ~~$40~~$20 million, respectively. During the nine months ended September 30, 2019, Dominion Energy, Virginia Power and Dominion Energy Gas recognized revenue of $92 million, $22 million and $40 million, respectively, from the beginning contract liability balances as the Companies fulfilled their obligations to provide service to their customers. The Companies’ contract liabilities are recorded in other current liabilities and other deferred credits and other liabilities in the 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 and 2019 Dominion Energy recognized revenue of $106 million and $91 million, respectively, from the beginning contract liability balances. During the six months ended June 30, 2020 and 2019, Virginia Power recognized $24 million and $22 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						Dominion Energy Gas
Nine Months Ended September 30,	2019			2018			2019			2018			2019			2018
Six Months Ended June 30,																			2020			2019			2020			2019			2020				2019
U.S. statutory rate		21.0	%		21.0	%		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		0.2			3.3			4.5			4.6			4.2			3.9			5.6			0.7			4.9			4.7			(255.3	)			3.0
Investment tax credits		(5.7	)		(0.9	)		(5.3	)		(1.4	)		—			—			3.9			(3.8	)		(11.3	)		(5.2	)		—				—
Production tax credits		(1.2	)		(0.7	)		(0.8	)		(0.7	)		—			—			0.3			(1.1	)		(2.0	)		(0.8	)		—				—
Reversal of excess deferred income taxes		(6.8	)		(1.5	)		(4.1	)		(1.9	)		(1.1	)		(1.3	)		1.5			(6.9	)		(0.8	)		(4.2	)		(68.4	)			(0.9	)
Federal legislative change		—			2.0			—			(0.2	)		—			2.0
State legislative change		—			(0.8	)		—			—			—			0.1
Write-off of regulatory assets		33.5			—			—			—			—			—			(4.2	)		(41.6	)		—			—			189.4				—
AFUDC - equity		(2.0	)		(0.9	)		—			(0.5	)		(0.6	)		(0.4	)		0.5			(1.9	)		(0.6	)		(0.1	)		(36.8	)			(0.5	)
Other, net		(2.7	)		(1.0	)		(1.2	)		(0.3	)		(1.3	)		0.7			0.9			(0.3	)		1.1			0.4			(467.1	)	⁽¹⁾		(4.3	)	⁽¹⁾
Effective tax rate		36.3	%		20.5	%		14.1	%		20.6	%		22.2	%		26.0	%		29.5	%		(33.9	)%		12.3	%		15.8	%		(617.2	)%			18.3	%

(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 ~~the portion of~~ excess deferred income tax amortization in ~~2019.~~2020. The reversal of these excess deferred income taxes will impact the effective tax rate and ~~may ultimately impact~~ rates charged to customers. ~~As described in~~See Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018, the Companies decreased revenue and increased regulatory liabilities to offset these deferred tax impacts in accordance with applicable regulatory commission orders or formula rate mechanisms. See Note 132019 for ~~current year developments.~~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 part of the SCANA Combination, Dominion Energy acquired SCANA’s unrecognized tax benefits of $106 million. In the first quarter of 2019, Dominion Energy completed the evaluation of a state income tax position acquired in the SCANA Combination that increased unrecognized tax benefits by $51 million. In the second quarter, Dominion Energy completed the evaluation of a federal income tax position acquired in the SCANA Combination that increased unrecognized tax benefits by $18 million. In the third quarter, DESC’s unrecognized tax benefits increased by $1 million and both accrued interest and penalties increased by $7 million. In total, these adjustments resulted in an increase to goodwill of $72 million and had no impact on Dominion Energy’s income tax expense, interest expense or other income.

As of ~~September~~June 30, ~~2019,~~2020, there have been no ~~other~~ 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, ~~2018,~~2019, for a discussion of these unrecognized tax benefits.

The 2017 Tax Reform Act limits the deductibility of interest expense to 30% of adjusted taxable income for certain businesses, with any disallowed interest carried forward indefinitely. Subject to additional guidance in yet to be finalized regulations, the Companies expect interest expense to be deductible in 2019.

Note 6. Earnings Per Share

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

	Three Months Ended September 30,						Nine Months Ended September 30,					Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018		2020			2019			2020			2019
(millions, except EPS)
Net income attributable to Dominion Energy	$	975		$	854	��	$	349		$	1,806
Series A Preferred Stock dividends		(7	)		—			(8	)		—
Net income attributable to Dominion Energy - Basic		968			854			341			1,806
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	)		—			(26	)		—		—			(13	)		—			—
Net income attributable to Dominion Energy - Diluted		955			854			315			1,806
Average shares of common stock outstanding – Basic		813.0			653.9			802.9			652.4
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		—			1.0			0.1			0.4		—			0.1			—			—
Average shares of common stock outstanding – Diluted		813.0			654.9			803.0			652.8		839.4			802.6			838.8			797.8
Earnings Per Common Share – Basic	$	1.19		$	1.31		$	0.42		$	2.77	$	(1.41	)	$	0.07		$	(1.75	)	$	(0.78	)
Earnings Per Common Share – Diluted	$	1.17		$	1.30		$	0.39		$	2.77	$	(1.41	)	$	0.05		$	(1.75	)	$	(0.78	)

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 are potentially dilutive securities. The forward stock purchase contracts included within the 2019 Equity Units were excluded from the calculation of diluted EPS for the three ~~and nine~~ months ended ~~September~~June 30, 2019, 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 ~~and nine~~ months ended ~~September~~June 30, 2019, based upon the expectation that the conversion will be settled in cash rather than through the

issuance of Dominion Energy common stock. The 2016 Equity Units ~~were~~are potentially dilutive securities, but were excluded from the calculation of diluted EPS for the three ~~and nine~~ months ended ~~September~~June 30, 2019 ~~and 2018,~~ as the dilutive stock price threshold was not met. The forward sales agreements, effective April 2018, were potentially dilutive securities but had no effect on the calculation of diluted EPS for the three and nine months ended September 30, 2018. The Dominion Energy Midstream convertible preferred units were potentially dilutive securities but had no effect on the calculation of diluted EPS for the three and nine months ended September 30, 2018. In calculating diluted EPS in connection with the Dominion Energy Midstream convertible preferred units, Dominion Energy applied the if-converted method.

Note 7. Accumulated Other Comprehensive Income

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 September 30, 2019
Three Months Ended June 30, 2020
Beginning balance	$	(389	)	$	30		$	(1,322	)	$	(2	)	$	(1,683	)	$	(651	)	$	37		$	(1,402	)	$	(2	)	$	(2,018	)
Other comprehensive income before reclassifications: gains (losses)		(107	)		8			(4	)		(1	)		(104	)		2			19			(1	)		—			20
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(6	)		(4	)		20			—			10			5			(5	)		18			—			18
Net current period other comprehensive income (loss)		(113	)		4			16			(1	)		(94	)		7			14			17			—			38
Ending balance	$	(502	)	$	34		$	(1,306	)	$	(3	)	$	(1,777	)	$	(644	)	$	51		$	(1,385	)	$	(2	)	$	(1,980	)
Three Months Ended September 30, 2018
Three Months Ended June 30, 2019
Beginning balance	$	(248	)	$	(2	)	$	(1,286	)	$	(2	)	$	(1,538	)	$	(290	)	$	18		$	(1,457	)	$	(2	)	$	(1,731	)
Other comprehensive income before reclassifications: gains (losses)		(27	)		(6	)		—			—			(33	)		(78	)		13			113			—			48
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		30			3			18			—			51			(21	)		(1	)		22			—			—
Net current period other comprehensive income (loss)		3			(3	)		18			—			18			(99	)		12			135			—			48
Ending balance	$	(245	)	$	(5	)	$	(1,268	)	$	(2	)	$	(1,520	)	$	(389	)	$	30		$	(1,322	)	$	(2	)	$	(1,683	)
Nine Months Ended September 30, 2019
Six Months Ended June 30, 2020
Beginning balance	$	(235	)	$	2		$	(1,465	)	$	(2	)	$	(1,700	)	$	(407	)	$	37		$	(1,421	)	$	(2	)	$	(1,793	)
Other comprehensive income before reclassifications: gains (losses)		(209	)		37			109			(1	)		(64	)		(264	)		28			(1	)		—			(237	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(58	)		(5	)		50			—			(13	)		27			(14	)		37			—			50
Net current period other comprehensive income (loss)		(267	)		32			159			(1	)		(77	)		(237	)		14			36			—			(187	)
Ending balance	$	(502	)	$	34		$	(1,306	)	$	(3	)	$	(1,777	)	$	(644	)	$	51		$	(1,385	)	$	(2	)	$	(1,980	)
Nine Months Ended September 30, 2018
Six Months Ended June 30, 2019
Beginning balance	$	(302	)	$	747		$	(1,101	)	$	(3	)	$	(659	)	$	(235	)	$	2		$	(1,465	)	$	(2	)	$	(1,700	)
Other comprehensive income before reclassifications: gains (losses)		51			(24	)		—			1			28			(102	)		29			113			—			40
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		71			4			60			—			135			(52	)		(1	)		30			—			(23	)
Net current period other comprehensive income (loss)		122			(20	)		60			1			163			(154	)		28			143			—			17
Cumulative-effect of changes in accounting principle		(64	)		(732	)		(227	)		—			(1,023	)
Less other comprehensive income attributable to noncontrolling interest		1			—			—			—			1
Ending balance	$	(245	)	$	(5	)	$	(1,268	)	$	(2	)	$	(1,520	)	$	(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)
Six Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(16	)	Operating revenue
		3		Purchased gas
Interest rate contracts		49		Interest and related charges
Total		36
Tax		(9	)	Income tax expense (benefit)
Total, net of tax	$	27
Unrealized (gains) and losses on investment securities:
Realized (gains) losses on sale of securities	$	(18	)	Other income
Total		(18	)
Tax		4		Income tax expense (benefit)
Total, net of tax	$	(14	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(11	)	Other income
Amortization of actuarial losses		61		Other income
Total		50
Tax		(13	)	Income tax expense (benefit)
Total, net of tax	$	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

Details about AOCI components

Amounts
reclassified
from AOCI

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

Three Months Ended September 30, 2019

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

Commodity contracts

$
(35
)

Operating revenue

2

Purchased gas
Interest rate contracts

14

Interest and related charges
Foreign currency contracts

12

Other income
Total

(7
)

Tax

1

Income tax expense
Total, net of tax

$
(6
)

Unrealized (gains) and losses on investment securities:

Realized (gain) loss on sale of securities

$
(5
)

Other income
Total

(5
)

Tax

1

Income tax expense
Total, net of tax

$
(4
)

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

(6
)

Income tax expense
Total, net of tax

$
20

Three Months Ended September 30, 2018

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

Commodity contracts

$
26

Operating revenue
Interest rate contracts

12

Interest and related charges
Foreign currency contracts

2

Other income
Total

40

Tax

(10
)

Income tax expense
Total, net of tax

$
30

Unrealized (gains) and losses on investment securities:

Realized (gain) loss on sale of securities

$
3

Other income
Total

3

Tax

—

Income tax expense
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

30

Other income
Total

25

Tax

(7
)

Income tax expense
Total, net of tax

$
18

Details about AOCI components

Amounts
reclassified
from AOCI

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

Nine Months Ended September 30, 2019

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

Commodity contracts

$
(127
)

Operating revenue

(1
)

Purchased gas
Interest rate contracts

37

Interest and related charges
Foreign currency contracts

14

Other income
Total

(77
)

Tax

19

Income tax expense
Total, net of tax

$
(58
)

Unrealized (gains) and losses on investment securities:

Realized (gain) loss on sale of securities

$
(6
)

Other income
Total

(6
)

Tax

1

Income tax expense
Total, net of tax

$
(5
)

Unrecognized pension and other postretirement benefit costs:

Amortization of prior-service costs (credits)

$
(18
)

Other income
Amortization of actuarial losses

85

Other income
Total

67

Tax

(17
)

Income tax expense
Total, net of tax

$
50

Nine Months Ended September 30, 2018

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

Commodity contracts

$
55

Operating revenue

2

Purchased gas

(8
)

Electric fuel and other energy-related purchases
Interest rate contracts

36

Interest and related charges
Foreign currency contracts

10

Other income
Total

95

Tax

(24
)

Income tax expense
Total, net of tax

$
71

Unrealized (gains) and losses on investment securities:

Realized (gain) loss on sale of securities

$
5

Other income
Total

5

Tax

(1
)

Income tax expense
Total, net of tax

$
4

Unrecognized pension and other postretirement benefit costs:

Amortization of prior-service costs (credits)

$
(16
)

Other income
Amortization of actuarial losses

91

Other income
Total

75

Tax

(15
)

Income tax expense
Total, net of tax

$
60

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			Deferred gains and losses on derivatives- hedging activities			Unrealized gains and losses on investment securities			Total
(millions)
Three Months Ended September 30, 2019
Three Months Ended June 30, 2020
Beginning balance	$	(30	)	$	4		$	(26	)	$	(79	)	$	4		$	(75	)
Other comprehensive income before reclassifications: gains (losses)		(16	)		1			(15	)		1			6			7
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		—			—			—			—			(2	)		(2	)
Net current period other comprehensive income (loss)		(16	)		1			(15	)		1			4			5
Ending balance	$	(46	)	$	5		$	(41	)	$	(78	)	$	8		$	(70	)
Three Months Ended September 30, 2018
Three Months Ended June 30, 2019
Beginning balance	$	(8	)	$	(1	)	$	(9	)	$	(20	)	$	3		$	(17	)
Other comprehensive income before reclassifications: gains (losses)		3			—			3			(11	)		2			(9	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		—			—			—			1			(1	)		—
Net current period other comprehensive income (loss)		3			—			3			(10	)		1			(9	)
Ending balance	$	(5	)	$	(1	)	$	(6	)	$	(30	)	$	4		$	(26	)
Nine Months Ended September 30, 2019
Six Months Ended June 30, 2020
Beginning balance	$	(13	)	$	1		$	(12	)	$	(34	)	$	5		$	(29	)
Other comprehensive income before reclassifications: gains (losses)		(34	)		5			(29	)		(44	)		4			(40	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		1			(1	)		—			—			(1	)		(1	)
Net current period other comprehensive income (loss)		(33	)		4			(29	)		(44	)		3			(41	)
Ending balance	$	(46	)	$	5		$	(41	)	$	(78	)	$	8		$	(70	)
Nine Months Ended September 30, 2018
Six Months Ended June 30, 2019
Beginning balance	$	(12	)	$	74		$	62		$	(13	)	$	1		$	(12	)
Other comprehensive income before reclassifications: gains (losses)		10			(2	)		8			(18	)		4			(14	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		—			—			—			1			(1	)		—
Net current period other comprehensive income (loss)		10			(2	)		8			(17	)		3			(14	)
Cumulative-effect of changes in accounting principle		(3	)		(73	)		(76	)
Ending balance	$	(5	)	$	(1	)	$	(6	)	$	(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 ~~nine~~six months ended ~~September~~June 30, ~~2019 and 2018.~~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			Unrecognized pension costs			Total
(millions)
Three Months Ended September 30, 2019
Three Months Ended June 30, 2020
Beginning balance										$	(166	)	$	(105	)	$	(271	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾											(2	)		2			—
Net current period other comprehensive income (loss)											(2	)		2			—
Ending balance										$	(168	)	$	(103	)	$	(271	)
Three Months Ended June 30, 2019
Beginning balance	$	(74	)	$	(112	)	$	(186	)	$	(48	)	$	(143	)	$	(191	)
Other comprehensive income before reclassifications: gains (losses)		(36	)		(1	)		(37	)		(24	)		29			5
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		9			1			10			(2	)		2			—
Net current period other comprehensive income (loss)		(27	)		—			(27	)		(26	)		31			5
Ending balance	$	(101	)	$	(112	)	$	(213	)	$	(74	)	$	(112	)	$	(186	)
Three Months Ended September 30, 2018
Six Months Ended June 30, 2020
Beginning balance	$	(24	)	$	(94	)	$	(118	)	$	(81	)	$	(106	)	$	(187	)
Other comprehensive income before reclassifications: gains (losses)		3			—			3			(91	)		—			(91	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		5			2			7			4			3			7
Net current period other comprehensive income (loss)		8			2			10			(87	)		3			(84	)
Ending balance	$	(16	)	$	(92	)	$	(108	)	$	(168	)	$	(103	)	$	(271	)
Nine Months Ended September 30, 2019
Six Months Ended June 30, 2019
Beginning balance	$	(25	)	$	(144	)	$	(169	)	$	(25	)	$	(144	)	$	(169	)
Other comprehensive income before reclassifications: gains (losses)		(87	)		28			(59	)		(51	)		29			(22	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		11			4			15			1			3			4
Net current period other comprehensive income (loss)		(76	)		32			(44	)		(50	)		32			(18	)
Less other comprehensive income (loss) attributable to noncontrolling interest											(1	)		—			(1	)
Ending balance	$	(101	)	$	(112	)	$	(213	)	$	(74	)	$	(112	)	$	(186	)
Nine Months Ended September 30, 2018
Beginning balance	$	(23	)	$	(75	)	$	(98	)
Other comprehensive income before reclassifications: gains (losses)		(4	)		—			(4	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		16			4			20
Net current period other comprehensive income (loss)		12			4			16
Cumulative-effect of changes in accounting principle		(5	)		(21	)		(26	)
Ending balance	$	(16	)	$	(92	)	$	(108	)

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

The following table presents Dominion Energy Gas’ 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 September 30, 2019
Three Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts					$	4		Interest and related charges
Foreign currency contracts						(6	)	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
Tax						—		Income tax expense (benefit)
Total, net of tax					$	2
Three Months Ended June 30, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts					$	2		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
Tax						—		Income tax expense (benefit)
Total, net of tax					$	2
Six Months Ended June 30, 2020
Deferred (gains) and losses on derivatives-hedging activities:
Interest rate contracts					$	6		Interest and related charges
Total						6
Tax						(2	)	Income tax expense (benefit)
Total, net of tax					$	4
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
Six Months Ended June 30, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(2	)	Operating revenue	$	(2	)	Net income from discontinued operations
Interest rate contracts		2		Interest and related charges		1		Interest and related charges
Foreign currency contracts		12		Other income		2		Other income
Total		12				1
Tax		(3	)	Income tax expense		—		Income tax expense (benefit)
Total, net of tax	$	9			$	1
Unrecognized pension costs:
Unrecognized pension and other postretirement benefit costs:
Actuarial losses	$	1		Other income	$	4		Other income
Total		1				4
Tax		—		Income tax expense		(1	)	Income tax expense (benefit)
Total, net of tax	$	1			$	3
Three Months Ended September 30, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	3		Operating revenue
Interest rate contracts		2		Interest and related charges
Foreign currency contracts		2		Other income
Total		7
Tax		(2	)	Income tax expense
Total, net of tax	$	5
Unrecognized pension costs:
Actuarial losses	$	2		Other income
Total		2
Tax		—		Income tax expense
Total, net of tax	$	2
Nine Months Ended September 30, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(4	)	Operating revenue
Interest rate contracts		5		Interest and related charges
Foreign currency contracts		14		Other income
Total		15
Tax		(4	)	Income tax expense
Total, net of tax	$	11
Unrecognized pension costs:
Actuarial losses	$	5		Other income
Total		5
Tax		(1	)	Income tax expense
Total, net of tax	$	4
Nine Months Ended September 30, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	8		Operating revenue
Interest rate contracts		4		Interest and related charges
Foreign currency contracts		10		Other income
Total		22
Tax		(6	)	Income tax expense
Total, net of tax	$	16
Unrecognized pension costs:
Actuarial losses	$	5		Other income
Total		5
Tax		(1	)	Income tax expense

~~Total, net of tax~~

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, ~~2018.~~2019. 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 ~~September~~June 30, ~~2019.~~2020. 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 and futures:
Physical and financial forwards:
Natural gas⁽²⁾	$	13	Discounted cash flow	Market price (per Dth)	⁽³⁾	(1) - 6		—		$	112	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 3		(1	)
FTRs		5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(2) - 8		1			18	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 5		1
Physical options:
Natural gas		2	Option model	Market price (per Dth)	⁽³⁾	1 - 6		4
				Price volatility	⁽⁴⁾	1% - 70%		47	%
Total assets	$	20								$	130
Liabilities
Physical and financial forwards:
Natural gas⁽²⁾	$	10	Discounted Cash Flow	Market price (per Dth)	⁽³⁾	(2) - 7		(1	)
Financial forwards:
FTRs		5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(5) - 3		—		$	5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(5) - 5		—
Physical options:
Natural gas		6	Option model	Market price (per Dth)	⁽³⁾	1 - 6		3			2	Option model	Market price (per Dth)	⁽³⁾	1 - 5		2
				Price volatility	⁽⁴⁾	1% - 71%		26	%				Price volatility	⁽⁴⁾	56% - 72%		66	%
Total liabilities	$	21								$	7

(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.

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)

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 September 30, 2019
At June 30, 2020
Assets
Derivatives:
Commodity	$	6	$	54	$	20	$	80	$	—	$	52	$	130	$	182
Interest rate		—		10		—		10		—		34		—		34
Foreign currency		—		3		—		3
Investments⁽¹⁾:
Equity securities:
U.S.		3,881		—		—		3,881		3,817		—		—		3,817
Fixed income securities:
Fixed income:
Corporate debt instruments		—		472		—		472		—		624		—		624
Government securities		474		694		—		1,168		488		746		—		1,234
Cash equivalents and other		26		5		—		31		19		12		—		31
Total assets	$	4,387	$	1,238	$	20	$	5,645	$	4,324	$	1,468	$	130	$	5,922
Liabilities
Derivatives:
Commodity	$	14	$	45	$	21	$	80	$	—	$	43	$	7	$	50
Interest rate		—		850		—		850		—		1,272		—		1,272
Foreign currency		—		4		—		4		—		12		—		12
Total liabilities	$	14	$	899	$	21	$	934	$	—	$	1,327	$	7	$	1,334
At December 31, 2018
At December 31, 2019
Assets
Derivatives:
Commodity	$	—	$	180	$	70	$	250	$	—	$	55	$	19	$	74
Interest rate		—		18		—		18		—		11		—		11
Foreign currency		—		26		—		26		—		8		—		8
Investments⁽¹⁾:
Equity securities:
U.S.		3,277		—		—		3,277		4,195		—		—		4,195
Fixed income securities:
Fixed income:
Corporate debt instruments		—		431		—		431		—		463		—		463
Government securities		455		688		—		1,143		473		719		—		1,192
Cash equivalents and other		11		—		—		11		19		1		—		20
Total assets	$	3,743	$	1,343	$	70	$	5,156	$	4,687	$	1,257	$	19	$	5,963
Liabilities
Derivatives:
Commodity	$	—	$	129	$	6	$	135	$	—	$	75	$	56	$	131
Interest rate		—		142		—		142		—		606		—		606
Foreign currency		—		2		—		2		—		3		—		3
Total liabilities	$	—	$	273	$	6	$	279	$	—	$	684	$	56	$	740

(1)

Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes ~~$262~~$296 million and ~~$220~~$274 million of assets at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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						Nine Months Ended						Three Months Ended						Six Months Ended
	September 30,						September 30,						June 30,						June 30,
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Beginning balance	$	75		$	119		$	64		$	150		$	43		$	53		$	(37	)	$	64
Total realized and unrealized gains (losses):
Included in earnings:
Operating revenue		—			—			2			(2	)		—			3			—			2
Purchased gas		—			—			1			—			—			1			—			1
Electric fuel and other energy-related purchases		(5	)		(7	)		(12	)		(25	)		(4	)		(3	)		(26	)		(7	)
Included in other comprehensive income		—			—			—			1
Included in regulatory assets/liabilities		(76	)		(16	)		(51	)		(26	)		80			18			160			25
Settlements		5			(4	)		7			(7	)		4			3			26			2
Purchases		—			—			(10	)		—			—			—			—			(10	)
Transfers out of Level 3		—			—			(2	)		1			—			—			—			(2	)
Ending balance	$	(1	)	$	92		$	(1	)	$	92		$	123		$	75		$	123		$	75
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		$	—		$	2
Purchased gas		—			—			1			—			—			1			—			1
Total	$	—		$	—		$	3		$	—		$	—		$	3		$	—		$	3

There were no 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 and 2019.

Virginia Power

The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at ~~September~~June 30, ~~2019.~~2020. 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 and futures:
Physical and financial forwards:
Natural gas⁽²⁾	$	12	Discounted cash flow	Market price (per Dth)	⁽³⁾	(1) - 3		—		$	112	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 2		(1	)
FTRs		5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(2) - 8		1			18	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 5		1
Total assets	$	17								$	130
Liabilities
Physical and financial forwards:
Natural gas⁽²⁾	$	10	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 6		(1	)
Financial forwards:
FTRs		5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(5) - 3		—		$	5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(5) - 5		—
Physical options:				��
Natural gas		1	Option model	Market price (per Dth)	⁽³⁾	1 - 6		3			2	Option model	Market price (per Dth)	⁽³⁾	1 - 5		2
				Price volatility	⁽⁴⁾	24% - 52%		35	%				Price volatility	⁽⁴⁾	56% - 72%		66	%
Total liabilities	$	16								$	7

(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.

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 September 30, 2019
At June 30, 2020
Assets
Derivatives:
Commodity	$	—	$	3	$	17	$	20	$	—	$	3	$	130	$	133
Investments⁽¹⁾:
Equity securities:
U.S.		1,783		—		—		1,783		1,787		—		—		1,787
Fixed income securities:
Fixed income:
Corporate debt instruments										—		354		—		354
Government securities										184		306		—		490
Total assets									$	1,971	$	663	$	130	$	2,764
Liabilities
Derivatives:
Commodity									$	—	$	17	$	7	$	24
Interest rate										—		980		—		980
Total liabilities									$	—	$	997	$	7	$	1,004
At December 31, 2019
Assets
Derivatives:
Commodity									$	—	$	3	$	19	$	22
Interest rate										—		2		—		2
Investments⁽¹⁾:
Equity securities:
U.S.										1,920		—		—		1,920
Fixed income:
Corporate debt instruments		—		273		—		273		—		256		—		256
Government securities		184		337		—		521		186		361		—		547
Cash equivalents and other		6		—		—		6		—		1		—		1
Total assets	$	1,973	$	613	$	17	$	2,603	$	2,106	$	623	$	19	$	2,748
Liabilities
Derivatives:
Commodity	$	—	$	17	$	16	$	33	$	—	$	47	$	56	$	103
Interest rate		—		521		—		521		—		363		—		363
Total liabilities	$	—	$	538	$	16	$	554	$	—	$	410	$	56	$	466
At December 31, 2018
Assets
Derivatives:
Commodity	$	—	$	24	$	66	$	90
Interest rate		—		3		—		3
Investments⁽¹⁾:
Equity securities:
U.S.		1,476		—		—		1,476
Fixed income securities:
Corporate debt instruments		—		221		—		221
Government securities		164		343		—		507
Total assets	$	1,640	$	591	$	66	$	2,297
Liabilities
Derivatives:
Commodity	$	—	$	9	$	6	$	15
Interest rate		—		88		—		88
Total liabilities	$	—	$	97	$	6	$	103

(1)

Includes investments held in the nuclear decommissioning trusts. Excludes ~~$152~~$154 million and ~~$160~~$159 million of assets at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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						Nine Months Ended						Three Months Ended						Six Months Ended
	September 30,						September 30,						June 30,						June 30,
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Beginning balance	$	77		$	115		$	60		$	147		$	43		$	59		$	(37	)	$	60
Total realized and unrealized losses:
Total realized and unrealized gains (losses):
Included in earnings:
Electric fuel and other energy-related purchases		(5	)		(6	)		(12	)		(25	)		(4	)		(3	)		(26	)		(7	)
Included in regulatory assets/liabilities		(76	)		(19	)		(50	)		(30	)		80			18			160			26
Settlements		5			(4	)		3			(6	)		4			3			26			(2	)
Ending balance	$	1		$	86		$	1		$	86		$	123		$	77		$	123		$	77

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 ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018.~~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.

	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
(millions)
At September 30, 2019
At June 30, 2020
Liabilities
Interest rate									$	—	$	192	$	—	$	192
Foreign currency										—		12		—		12
Total liabilities									$	—	$	204	$	—	$	204
At December 31, 2019
Assets
Commodity	$	—	$	2	$	—	$	2
Foreign currency		—		3		—		3	$	—	$	8	$	—	$	8
Total assets	$	—	$	5	$	—	$	5	$	—	$	8	$	—	$	8
Liabilities
Interest rate	$	—	$	113	$	—	$	113	$	—	$	83	$	—	$	83
Foreign currency		—		4		—		4		—		3		—		3
Total liabilities	$	—	$	117	$	—	$	117	$	—	$	86	$	—	$	86
At December 31, 2018
Assets
Commodity	$	—	$	3	$	—	$	3
Foreign currency		—		26		—		26
Total assets	$	—	$	29	$	—	$	29
Liabilities
Interest rate	$	—	$	17	$	—	$	17
Foreign currency		—		2		—		2
Total liabilities	$	—	$	19	$	—	$	19

The following table presents the net change in Dominion Energy Gas’ assets and liabilities for derivatives measured at fair value on a recurring basis and included in the Level 3 fair value category. There were 0 net changes in assets and liabilities measured at fair value on a recurring basis and included in the Level 3 fair value category for the three and nine months ended September 30, 2019 and the three months ended September 30, 2018.

Nine Months Ended

September 30,

2018

(millions)

Beginning balance

$
(2
)
Total realized and unrealized gains:

Included in other comprehensive income

1

Transfers out of Level 3

1

Ending balance

$
—

There were no gains or losses included in earnings in the Level 3 fair value category for the nine months ended September 30, 2018. 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 nine months ended September 30, 2018.

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, ~~and cash equivalents,~~ 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:

	September 30, 2019				December 31, 2018				June 30, 2020				December 31, 2019
	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, including securities due within one year⁽²⁾	$	34,662	$	38,894	$	29,952	$	31,045
Credit facility borrowings		—		—		73		73
Long-term debt⁽²⁾									$	36,060	$	42,151	$	32,055	$	36,155
Supplemental 364-Day credit facility borrowings										225		225		—		—
Junior subordinated notes⁽³⁾		3,797		3,951		3,430		3,358		3,408		3,554		4,797		4,953
Remarketable subordinated notes⁽³⁾		—		—		1,386		1,340
Virginia Power
Long-term debt, including securities due within one year⁽³⁾	$	11,795	$	13,732	$	11,671	$	12,400
Long-term debt⁽³⁾									$	12,328	$	15,189	$	12,326	$	14,281
Dominion Energy Gas
Long-term debt, including securities due within one year⁽⁴⁾	$	4,058	$	4,309	$	4,058	$	4,072
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 ~~issues~~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, discount or premium and foreign currency remeasurement adjustments. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, includes the valuation of certain fair value hedges associated with fixed rate debt of $6$4 million and ~~$(20)~~$4 million, respectively.

(3)	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, ~~2018.~~2019. 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 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, none of which are subject to restrictions. Cash collateral is used in the table below 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, 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 1918 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:

			September 30, 2019									December 31, 2018							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 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	$	39		$	18	$	—	$	21	$	175		$	12	$	—	$	163	$	136	$	9	$	—	$	127	$	35	$	21	$	—	$	14
Exchange		37			26		—		11		68			68		—		—		45		20		7		18		37		21		—		16
Interest rate contracts:
Over-the-counter		10			4		—		6		18			1		—		17		34		14		—		20		11		3		—		8
Foreign currency contracts:
Over-the-counter		3			3		—		—		26			2		—		24		—		—		—		—		8		8		—		—
Total derivatives, subject to a master netting or similar arrangement	$	89		$	51	$	—	$	38	$	287		$	83	$	—	$	204	$	215	$	43	$	7	$	165	$	91	$	53	$	—	$	38

(1)	Excludes $4$1 million and $7$2 million of derivative assets at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively, which are not subject to master netting or similar arrangements.

			September 30, 2019									December 31, 2018						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 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	$	43		$	18	$	1	$	24	$	19	$	12	$	—	$	7	$	30	$	9	$	—	$	21	$	105	$	21	$	—	$	84
Exchange		34			26		8		—		115		68		47		—		20		20		—		—		21		21		—		—
Interest rate contracts:
Over-the-counter		850			4		41		805		142		1		—		141		1,272		14		22		1,236		606		8		35		563
Foreign currency contracts:
Over-the-counter		4			3		—		1		2		2		—		—		12		—		—		12		3		3		—		—
Total derivatives, subject to a master netting or similar arrangement	$	931		$	51	$	50	$	830	$	278	$	83	$	47	$	148	$	1,334	$	43	$	22	$	1,269	$	735	$	53	$	35	$	647

(1)	Excludes $3$— million and $1$5 million of derivative liabilities at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 ~~September~~June 30, ~~2019.~~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		Current		Noncurrent
Natural Gas (bcf):
Fixed price⁽¹⁾		125		63		69		32
Basis		256		541		236		538
Electricity (MWh):
Fixed price		3,262,550		369,850		4,964,045		2,775,850
FTRs		74,936,524		—		101,087,887		—
NGLs (Gal)		17,892,000		—
Liquids (Gal)⁽²⁾						26,460,000		—
Interest rate⁽²⁾⁽³⁾	$	850,000,000	$	5,384,447,114	$	1,950,000,000	$	6,576,403,434
Foreign currency⁽²⁾⁽³⁾	$	—	$	280,000,000
Foreign currency⁽³⁾					€	-	€	250,000,000

(1)	Includes options.

(2)	Includes NGLs.

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

~~(3)~~

~~Euro equivalent volumes are €250,000,000.~~

AOCI

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion Energy’s Consolidated Balance Sheet at ~~September~~June 30, ~~2019:~~2020:

	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)
Commodities:
Gas	$	(6	)	$	(5	)	27 months	$	(2	)	$	(2	)	18 months
Electricity		9			8		15 months		8			8		6 months
Other		2			2		6 months
NGL									—			—		6 months
Interest rate		(512	)		(49	)	387 months		(640	)		(59	)	378 months
Foreign currency		5			(3	)	81 months		(10	)		(4	)	72 months
Total	$	(502	)	$	(47	)		$	(644	)	$	(57	)

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) 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 in fair value hedges during the three and six months ended June 30, 2020. Gains and losses on derivatives in fair value hedge relationships were immaterial for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019 and 2018.~~2019.

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⁾
	September 30, 2019			December 31, 2018			September 30, 2019			December 31, 2018		June 30, 2020			December 31, 2019			June 30, 2020			December 31, 2019
(millions)
Long-term debt	$	(1,156	)	$	(1,631	)	$	(6	)	$	20	$	(1,154	)	$	(1,154	)	$	(4	)	$	(4	)

(1)	Includes ~~$(396) million~~$(1.1) billion and ~~$(892)~~$(397) million related to discontinued hedging relationships at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively.

(2)	Includes $4$(4) million and $8$3 million of hedging adjustments on discontinued hedging relationships at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively.

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)
September 30, 2019
June 30, 2020
ASSETS
Current Assets
Commodity							$	—	$	73	$	73
Interest rate								—		8		8
Total current derivative assets⁽¹⁾								—		81		81
Noncurrent Assets
Commodity								—		109		109
Interest rate								—		26		26
Total noncurrent derivative assets⁽²⁾								—		135		135
Total derivative assets							$	—	$	216	$	216
LIABILITIES
Current Liabilities
Commodity							$	—	$	42	$	42
Interest rate								514		25		539
Foreign currency								5		—		5
Total current derivative liabilities								519		67		586
Noncurrent Liabilities
Commodity								—		8		8
Interest rate								655		78		733
Foreign currency								7		—		7
Total noncurrent derivative liabilities⁽⁴⁾								662		86		748
Total derivative liabilities							$	1,181	$	153	$	1,334
December 31, 2019
ASSETS
Current Assets
Commodity	$	18	$	53	$	71	$	30	$	37	$	67
Interest rate		2		—		2		1		—		1
Total current derivative assets⁽¹⁾		20		53		73		31		37		68
Noncurrent Assets
Commodity		2		7		9		1		6		7
Interest rate		8		—		8		10		—		10
Foreign currency		3		—		3		8		—		8
Total noncurrent derivative assets⁽²⁾		13		7		20		19		6		25
Total derivative assets	$	33	$	60	$	93	$	50	$	43	$	93
LIABILITIES
Current Liabilities
Commodity	$	9	$	50	$	59	$	6	$	77	$	83
Interest rate		200		2		202		321		1		322
Foreign currency		4		—		4		3		—		3
Total current derivative liabilities⁽³⁾		213		52		265
Total current derivative liabilities								330		78		408
Noncurrent Liabilities
Commodity		2		19		21		1		47		48
Interest rate		627		21		648		267		17		284
Total noncurrent derivative liabilities⁽⁴⁾		629		40		669		268		64		332
Total derivative liabilities	$	842	$	92	$	934	$	598	$	142	$	740
December 31, 2018
ASSETS
Current Assets
Commodity	$	55	$	154	$	209
Interest rate		14		—		14
Total current derivative assets⁽¹⁾		69		154		223
Noncurrent Assets
Commodity		6		35		41
Interest rate		4		—		4
Foreign currency		26		—		26
Total noncurrent derivative assets⁽²⁾		36		35		71
Total derivative assets	$	105	$	189	$	294
LIABILITIES
Current Liabilities
Commodity	$	17	$	112	$	129
Interest rate		26		—		26
Foreign currency		2		—		2
Total current derivative liabilities⁽³⁾		45		112		157
Noncurrent Liabilities
Commodity		5		1		6
Interest rate		116		—		116
Total noncurrent derivative liabilities⁽⁴⁾		121		1		122
Total derivative liabilities	$	166	$	113	$	279

(1)	Current derivative assets ~~include amounts~~are presented in other 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 $242 million and $157 million in other current liabilities at September 30, 2019 and December 31. 2018, respectively, with the remainder recorded in 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 September 30, 2019
Three Months Ended June 30, 2020
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	35								$	9
Purchased gas					(2	)								—
Total commodity	$	(5	)	$	33		$	—		$	—		$	9		$	—
Interest rate⁽³⁾		(124	)		(14	)		(190	)		—			(22	)		14
Foreign currency⁽⁴⁾		(15	)		(12	)		—			6			6			—
Total	$	(144	)	$	7		$	(190	)	$	6		$	(7	)	$	14
Three Months Ended September 30, 2018
Three Months Ended June 30, 2019
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	(26	)							$	38
Total commodity	$	(58	)	$	(26	)	$	—		$	35		$	38		$	—
Interest rate⁽³⁾		23			(12	)		48			(142	)		(13	)		(131	)
Foreign currency⁽⁴⁾		(1	)		(2	)		—			2			4			—
Total	$	(36	)	$	(40	)	$	48		$	(105	)	$	29		$	(131	)
Nine Months Ended September 30, 2019
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	127
Purchased gas					1
Total commodity	$	96		$	128		$	—
Interest rate⁽³⁾		(350	)		(37	)		(405	)
Foreign currency⁽⁴⁾		(24	)		(14	)		—
Total	$	(278	)	$	77		$	(405	)
Nine Months Ended September 30, 2018
Six Months Ended June 30, 2020
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	(55	)							$	16
Purchased gas					(2	)								(3	)
Electric fuel and other energy-related purchases					8									—
Total commodity	$	(1	)	$	(49	)	$	—		$	—		$	13		$	—
Interest rate⁽³⁾		70		��	(36	)		141			(336	)		(49	)		(550	)
Foreign currency⁽⁴⁾		(1	)		(10	)		—			(17	)		—			—
Total	$	68		$	(95	)	$	141		$	(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 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.~~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						Nine Months Ended						Three Months Ended						Six Months Ended
	September 30,						September 30,						June 30,						June 30,
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	7		$	(5	)	$	37		$	(8	)	$	(10	)	$	27		$	55		$	30
Purchased gas		(10	)		1			(18	)		5			—			(11	)		(14	)		(8	)
Electric fuel and other energy-related purchases		(6	)		(7	)		(18	)		(23	)		(8	)		(3	)		(73	)		(12	)
Interest rate⁽²⁾														(25	)		—			(86	)		—
Total	$	(9	)	$	(11	)	$	1		$	(26	)	$	(43	)	$	13		$	(118	)	$	10

(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:

			September 30, 2019								December 31, 2018						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 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	$	17	$	15	$	—	$	2	$	64	$	6	$	—	$	58	$	129	$	5	$	—	$	124	$	19	$	18	$	—	$	1
Interest rate contracts:
Over-the-counter		—		—		—		—		3		—		—		3		—		—		—		—		2		—		—		2
Total derivatives, subject to a master netting or similar arrangement	$	17	$	15	$	—	$	2	$	67	$	6	$	—	$	61	$	129	$	5	$	—	$	124	$	21	$	18	$	—	$	3

(1)	Excludes $3$4 million and ~~$26~~$3 million of derivative assets at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively, which are not subject to master netting or similar arrangements.

			September 30, 2019								December 31, 2018						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 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	$	16	$	15	$	—	$	1	$	6	$	6	$	—	$	—	$	5	$	5	$	—	$	—	$	59	$	18	$	—	$	41
Interest rate contracts:
Over-the-counter		521		—		—		521		88		—		—		88		980		—		—		980		363		—		—		363
Total derivatives, subject to a master netting or similar arrangement	$	537	$	15	$	—	$	522	$	94	$	6	$	—	$	88	$	985	$	5	$	—	$	980	$	422	$	18	$	—	$	404

(1)	Excludes ~~$17~~$19 million and $9$44 million of derivative liabilities at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 ~~September~~June 30, ~~2019.~~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		Current		Noncurrent
Natural Gas (bcf):
Fixed price⁽¹⁾		44		16		38		8
Basis		151		472		143		507
Electricity (MWh):
FTRs		74,936,524		—		101,087,887		—
Interest rate⁽²⁾	$	550,000,000	$	1,200,000,000	$	900,000,000	$	1,150,000,000

(1)	Includes options.

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

AOCI

The following table presents selected information related to ~~losses~~gains (losses) on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at ~~September~~June 30, ~~2019:~~2020:

	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	$	(46	)	$	(1	)	387 months	$	(78	)	$	(1	)	378 months
Total	$	(46	)	$	(1	)		$	(78	)	$	(1	)

The amounts that will be reclassified from AOCI to earnings will generally be offset by the recognition of the hedged transactions (e.g., interest 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)
September 30, 2019
June 30, 2020
ASSETS
Current Assets
Commodity	$	—	$	19	$	19	$	—	$	31	$	31
Total current derivative assets⁽¹⁾		—		19		19		—		31		31
Noncurrent Assets
Commodity		—		1		1		—		102		102
Total noncurrent derivative assets⁽²⁾		—		1		1		—		102		102
Total derivative assets	$	—	$	20	$	20	$	—	$	133	$	133
LIABILITIES
Current Liabilities
Commodity	$	—	$	16	$	16	$	—	$	23	$	23
Interest rate		149		—		149		455		—		455
Total current derivative liabilities		149		16		165		455		23		478
Noncurrent Liabilities
Commodity		—	17			17		—	1			1
Interest rate		372		—		372		525		—		525
Total noncurrent derivatives liabilities⁽³⁾		372		17		389		525		1		526
Total derivative liabilities	$	521	$	33	$	554	$	980	$	24	$	1,004
December 31, 2018
December 31, 2019
ASSETS
Current Assets
Commodity	$	—	$	60	$	60	$	—	$	20	$	20
Interest rate		3		—		3
Total current derivative assets⁽¹⁾		3		60		63		—		20		20
Noncurrent Assets
Commodity		—		30		30		—		2		2
Interest rate								2		—		2
Total noncurrent derivative assets⁽²⁾		—		30		30		2		2		4
Total derivative assets	$	3	$	90	$	93	$	2	$	22	$	24
LIABILITIES
Current Liabilities
Commodity	$	—	$	15	$	15	$	—	$	58	$	58
Interest rate		10		—		10		185		—		185
Total current derivative liabilities		10		15		25
Total current derivatives liabilities⁽⁴⁾								185		58		243
Noncurrent Liabilities
Commodity								—		45		45
Interest rate		78		—		78		178		—		178
Total noncurrent derivatives liabilities⁽³⁾		78		—		78		178		45		223
Total derivative liabilities	$	88	$	15	$	103	$	363	$	103	$	466

(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 September 30, 2019
Three Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(21	)	$	—		$	(190	)	$	2		$	(1	)	$	13
Total	$	(21	)	$	—		$	(190	)	$	2		$	(1	)	$	13
Three Months Ended September 30, 2018
Three Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	4		$	—		$	48		$	(15	)	$	(1	)	$	(133	)
Total	$	4		$	—		$	48		$	(15	)	$	(1	)	$	(133	)
Nine Months Ended September 30, 2019
Six Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(45	)	$	(1	)	$	(408	)	$	(59	)	$	(1	)	$	(552	)
Total	$	(45	)	$	(1	)	$	(408	)	$	(59	)	$	(1	)	$	(552	)
Nine Months Ended September 30, 2018
Six Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	13		$	—		$	141		$	(24	)	$	(1	)	$	(218	)
Total	$	13		$	—		$	141		$	(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						Nine Months Ended						Three Months Ended						Six Months Ended
	September 30,						September 30,						June 30,						June 30,
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Derivative type and location of gains (losses):
Commodity⁽²⁾	$	(6	)	$	(9	)	$	(18	)	$	(12	)	$	(8	)	$	(3	)	$	(73	)	$	(12	)
Total	$	(6	)	$	(9	)	$	(18	)	$	(12	)	$	(8	)	$	(3	)	$	(73	)	$	(12	)

(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:

			September 30, 2019									December 31, 2018						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 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		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)
Commodity contracts:
Over-the-counter	$	2		$	—	$	—	$	2	$	3	$	—	$	—	$	3
Foreign currency contracts:
Over-the-counter		3			3		—		—		26		2		—		24	$	—	$	—	$	—	$	—	$	8	$	8	$	—	$	—
Total derivatives, subject to a master netting or similar arrangement	$	5		$	3	$	—	$	2	$	29	$	2	$	—	$	27	$	—	$	—	$	—	$	—	$	8	$	8	$	—	$	—

			September 30, 2019								December 31, 2018						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 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		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	$	113	$	—	$	—	$	113	$	17	$	—	$	—	$	17	$	192	$	—	$	—	$	192	$	83	$	5	$	—	$	78
Foreign currency contracts:
Over-the-counter		4		3		—		1		2		2		—		—		12		—		—		12		3		3		—		—
Total derivatives, subject to a master netting or similar arrangement	$	117	$	3	$	—	$	114	$	19	$	2	$	—	$	17	$	204	$	—	$	—	$	204	$	86	$	8	$	—	$	78

Volumes

The following table presents the volume of Dominion Energy Gas’ derivative activity at ~~September~~June 30, ~~2019.~~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

NGLs (Gal)

17,892,000

—

Interest rate⁽¹⁾

$
300,000,000

$
1,000,000,000

Foreign currency⁽¹⁾⁽²⁾

$
—

$
280,000,000

	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.

~~(2)~~

~~Euro equivalent volumes are €250,000,000.~~

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 ~~September~~June 30, ~~2019:~~2020:

	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)
Commodities:
NGLs	$	2		$	2		6 months
Interest rate		(108	)		(7	)	303 months	$	(158	)	$	(11	)	294 months
Foreign currency		5			(3	)	81 months		(10	)		(4	)	72 months
Total	$	(101	)	$	(8	)		$	(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 ~~market prices,~~ 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		Fair Value- Derivatives Under Hedge Accounting		Fair Value-Derivatives Not Under Hedge Accounting		Total Fair Value
(millions)
September 30, 2019
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
Current Assets
Commodity	$	2	$	—	$	2
Total current derivative assets⁽¹⁾		2		—		2
Noncurrent Assets
Foreign currency		3		—		3	$	8	$	—	$	8
Total noncurrent derivative assets⁽²⁾		3		—		3
Total noncurrent derivative assets⁽¹⁾								8		—		8
Total derivative assets	$	5	$	—	$	5	$	8	$	—	$	8
LIABILITIES
Current Liabilities
Interest rate	$	47	$	—	$	47	$	30	$	—	$	30
Foreign currency		4		—		4		3		—		3
Total current derivative liabilities⁽³⁾		51		—		51
Total current derivative liabilities⁽²⁾								33		—		33
Noncurrent Liabilities
Interest rate		66		—		66		53		—		53
Total noncurrent derivative liabilities⁽⁴⁾		66		—		66
Total noncurrent derivative liabilities⁽³⁾								53		—		53
Total derivative liabilities	$	117	$	—	$	117	$	86	$	—	$	86
December 31, 2018
ASSETS
Current Assets
Commodity	$	3	$	—	$	3
Total current derivative assets⁽¹⁾		3		—		3
Noncurrent Assets
Foreign currency		26		—		26
Total noncurrent derivative assets⁽²⁾		26		—		26
Total derivative assets	$	29	$	—	$	29
LIABILITIES
Current Liabilities
Interest rate	$	9	$	—	$	9
Foreign currency		2		—		2
Total current derivative liabilities⁽³⁾		11		—		11
Noncurrent Liabilities
Interest rate		8		—		8
Total noncurrent derivative liabilities⁽⁴⁾		8		—		8
Total derivative liabilities	$	19	$	—	$	19

(1)	~~Current derivative assets are presented in other current assets in Dominion Energy Gas’ Consolidated Balance Sheets.~~

~~(2)~~

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

~~(3)~~(2)

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

~~(4)~~(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			Amount of Gain (Loss) Recognized in AOCI on Derivatives⁽¹⁾			Amount of Gain (Loss) Reclassified From AOCI to Income
(millions)
Three Months Ended September 30, 2019
Derivative Type and Location of Gains (Losses):
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:
Operating revenue				$	2
Net income from discontinued operations										$	—
Total commodity	$	1		$	2		$	3		$	—
Interest rate⁽²⁾		(36	)		(2	)		(36	)		(2	)
Foreign currency⁽³⁾		(14	)		(12	)		1			4
Total	$	(49	)	$	(12	)	$	(32	)	$	2
Three Months Ended September 30, 2018
Derivative Type and Location of Gains (Losses):
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:
Operating revenue				$	(3	)
Net income from discontinued operations										$	2
Total commodity	$	(5	)	$	(3	)	$	2		$	2
Interest rate⁽²⁾		10			(2	)		(60	)		(1	)
Foreign currency⁽³⁾		(1	)		(2	)		(10	)		(2	)
Total	$	4		$	(7	)	$	(68	)	$	(1	)
Nine Months Ended September 30, 2019
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	4
Total commodity	$	3		$	4
Interest rate⁽²⁾		(96	)		(5	)
Foreign currency⁽³⁾		(24	)		(14	)
Total	$	(117	)	$	(15	)
Nine Months Ended September 30, 2018
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(8	)
Total commodity	$	(11	)	$	(8	)
Interest rate⁽²⁾		6			(4	)
Foreign currency⁽³⁾		(1	)		(10	)
Total	$	(6	)	$	(22	)

(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 ~~$114~~$121 million and ~~$111~~$120 million at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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				Fair Value		Amortized Cost			Total Unrealized Gains		Total Unrealized Losses				Allowance for Credit Losses			Fair Value
(millions)
September 30, 2019
June 30, 2020
Equity securities:⁽¹⁾
U.S.	$	1,787	$	2,169	$	(30	)		$	3,926	$	1,701		$	2,221	$	(71	)		$	—		$	3,851
Fixed income securities:⁽²⁾
Corporate debt instruments		442		30		—				472		577			48		(1	)			—			624
Government securities		1,082		44		(4	)			1,122		1,119			62		(1	)			—			1,180
Common/collective trust funds		105		4		—				109		146			2		—				—			148
Insurance contracts		210		—		—				210		223			—		—				—			223
Cash equivalents and other⁽³⁾		21		—		—				21		(8	)		2		(2	)			—			(8	)
Total	$	3,647	$	2,247	$	(34	)	⁽⁴⁾	$	5,860	$	3,758		$	2,335	$	(75	)	⁽⁴⁾	$	—	⁽⁵⁾	$	6,018
December 31, 2018
December 31, 2019
Equity securities:⁽¹⁾
U.S.	$	1,741	$	1,640	$	(51	)		$	3,330	$	1,807		$	2,451	$	(20	)		$	—		$	4,238
Fixed income securities:⁽²⁾
Corporate debt instruments		435		5		(9	)			431		434			29		—				—			463
Government securities		1,092		17		(12	)			1,097		1,108			39		(2	)			—			1,145
Common/collective trust funds		76		—		—				76		115			4		—				—			119
Cash equivalents and other		4		—		—				4
Insurance contracts												214			—		—				—			214
Cash equivalents and other⁽³⁾												13			—		—				—			13
Total	$	3,348	$	1,662	$	(72	)	⁽⁴⁾	$	4,938	$	3,691		$	2,523	$	(22	)	⁽⁴⁾	$	—		$	6,192

(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~~.liability. Effective January 2020, changes in allowance for credit losses are included in other income.

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

(4)	The fair value of securities in an unrealized loss position was ~~$277~~$181 million and ~~$833~~$298 million at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 September 30,

Nine Months Ended September 30,

2019

2018

2019

2018

(millions)

Net gains recognized during the period

$
40

$
243

$
610

$
267

Less: Net gains recognized during the period
on securities sold during the period

(17
)

(7
)

(61
)

(42
)
Unrealized gains recognized during the period on
securities still held at September 30, 2019 and 2018⁽¹⁾

$
23

$
236

$
549

$
225

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

(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 ~~September~~June 30, ~~2019~~2020 by contractual maturity is as follows:

	Amount		Amount
(millions)
Due in one year or less	$	212	$	212
Due after one year through five years		412		486
Due after five years through ten years		360		485
Due after ten years		719		769
Total	$	1,703	$	1,952

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 September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018		2020		2019		2020		2019
(millions)
Proceeds from sales	$	429	$	457	$	1,311	$	1,301	$	1,058	$	376	$	1,660	$	882
Realized gains⁽¹⁾		53		24		152		96		74		56		140		99
Realized losses⁽¹⁾		25		18		75		60		61		27		130		50

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

~~Dominion Energy recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows:~~

Three Months Ended September 30,

Nine Months Ended September 30,

2019

2018

2019

2018

(millions)

Total other-than-temporary impairment losses

$
1

$
8

$
1

$
25

Losses recognized in other comprehensive income (before taxes)

(1
)

(8
)

(1
)

(25
)
Net impairment losses recognized in earnings

$
—

$
—

$
—

$
—

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				Fair Value		Amortized Cost			Total Unrealized Gains		Total Unrealized Losses				Allowance for Credit Losses			Fair Value
(millions)
September 30, 2019
June 30, 2020
Equity securities:⁽¹⁾
U.S.	$	890	$	1,013	$	(15	)		$	1,888	$	901		$	1,028	$	(46	)		$	—		$	1,883
Fixed income securities:⁽²⁾
Corporate debt instruments		257		16		—				273		328			26		—				—			354
Government securities		504		17		(1	)			520		467			23		(1	)			—			489
Common/collective trust funds		46		—		—				46		57			—		—				—			57
Cash equivalents and other⁽³⁾		11		—		—				11		(1	)		—		—				—			(1	)
Total	$	1,708	$	1,046	$	(16	)	⁽⁴⁾	$	2,738	$	1,752		$	1,077	$	(47	)	⁽⁴⁾	$	—	⁽⁵⁾	$	2,782
December 31, 2018
December 31, 2019
Equity securities:⁽¹⁾
U.S.	$	858	$	751	$	(24	)		$	1,585	$	894		$	1,144	$	(11	)		$	—		$	2,027
Fixed income securities:⁽²⁾
Corporate debt instruments		224		2		(5	)			221		241			15		—				—			256
Government securities		504		7		(5	)			506		534			14		(2	)			—			546
Common/collective trust funds		51		—		—				51		51			—		—				—			51
Cash equivalents and other⁽³⁾		6		—		—				6		1			—		—				—			1
Total	$	1,643	$	760	$	(34	)	⁽⁴⁾	$	2,369	$	1,721		$	1,173	$	(13	)	⁽⁴⁾	$	—		$	2,881

(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 in allowance for credit losses are included in other income.

(3)	Includes pending ~~sales~~ purchasesof securities of ~~$5 million and~~$6$1 million at ~~September~~June 30, ~~2019 and December 31, 2018, respectively.~~2020.

(4)	The fair value of securities in an unrealized loss position was ~~$164~~$74 million and ~~$404~~$185 million at ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 September 30,

Nine Months Ended September 30,

2019

2018

2019

2018

(millions)

Net gains recognized during the period

$
30

$
106

$
286

$
118

Less: Net gains recognized during the period
on securities sold during the period

(7
)

(3
)

(15
)

(26
)
Unrealized gains recognized during the period on
securities still held at September 30, 2019 and 2018⁽¹⁾

$
23

$
103

$
271

$
92

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

(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 ~~September~~June 30, ~~2019~~2020 by contractual maturity is as follows:

	Amount		Amount
(millions)
Due in one year or less	$	99	$	79
Due after one year through five years		183		227
Due after five years through ten years		180		273
Due after ten years		377		321
Total	$	839	$	900

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 September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018		2020		2019		2020		2019
(millions)
Proceeds from sales	$	230	$	237	$	677	$	651	$	236	$	194	$	530	$	447
Realized gains⁽¹⁾		21		11		46		44		24		15		55		25
Realized losses⁽¹⁾		6		5		18		17		17		3		48		12

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

Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds recognized in earnings for Virginia Power were immaterial for the three and nine months ended September 30, 2019 and 2018.

Equity Method Investments

Dominion Energy

Dominion Energy’s equity earnings (losses) on its investments totaled $(2.2) billion and $80 million for the six months ended June 30, 2020 and 2019, respectively. Dominion Energy received distributions of $46 million and $57 million for the six months ended June 30, 2020 and 2019, respectively. At June 30, 2020 and December 31, 2019, the net difference between the carrying amount of Dominion Energy’s investments and its share of underlying equity in net assets was $96 million and $110 million, respectively. At June 30, 2020, these differences are comprised of $175 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 million basis difference from Dominion Energy’s investments in Fowler Ridge, which is being amortized over the useful lives of the underlying assets, in Atlantic Coast Pipeline, which is being amortized over the term of its credit facility, and an unfunded commitment made to Align RNG.

Atlantic Coast Pipeline

In September 2014, Dominion Energy, along with Duke Energy and Southern, ~~Company Gas,~~ announced the formation of Atlantic Coast ~~Pipeline. The Atlantic Coast~~ Pipeline ~~partnership agreement includes provisions to allow Dominion Energy an option to purchase additional ownership interest in Atlantic Coast Pipeline to maintain a leading ownership percentage. As~~for the purpose of ~~September 30, 2019, the members hold the following membership interests: Dominion Energy, 48%; Duke, 47%; and Southern Company Gas, 5%.~~

~~Atlantic Coast Pipeline is focused on~~ constructing an approximately 600-mile natural gas pipeline running from West Virginia through Virginia to North Carolina. Subsidiaries and affiliates of ~~all 3 members plan~~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. includes a 50% noncontrolling 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.

Atlantic Coast Pipeline continues to be reflected as an equity method investment as the power to direct the activities most significant to Atlantic Coast Pipeline is ~~considered an equity method investment as~~shared with Duke Energy. As a result, Dominion Energy has the ability to exercise significant influence, but not control, over the investee. ~~See Note 15 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018 for more information.~~

Dominion Energy recorded contributions of $47 million and $147 million during the three months ended September 30, 2019 and 2018, respectively, and $175 million and $306 million during the nine months ended September 30, 2019 and 2018, respectively, to Atlantic Coast Pipeline. At September 30, 2019, Dominion Energy had $10 million of contributions payable toThe Atlantic Coast Pipeline ~~included within other current liabilities in the Consolidated Balance Sheets.~~

DETI provides services to Atlantic Coast Pipeline which totaled $24 million and $50 million for the three months ended September 30, 2019 and 2018, respectively, and $81 million and $156 million for the nine months ended September 30, 2019 and 2018, respectively, included in operating revenue in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income. Amounts receivable related to these services were $9 million and $13 million at September 30, 2019 and December 31, 2018, respectively, composed entirely of accrued unbilled revenue, included in other receivables in Dominion Energy and Dominion Energy Gas’ Consolidated Balance Sheets.

~~In October 2017, Dominion Energy entered into a guarantee agreement to support a portion of Atlantic Coast Pipeline’s obligation under its credit facility. See Note 18 for more information.~~

~~Atlantic Coast Pipeline is~~Project had been the subject of challenges in ~~state and~~ federal courts ~~and agencies,~~ 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 ~~U.S.~~ Army Corps of Engineers 404 permit, the air permit for a compressor station at Buckingham, Virginia, ~~the FERC Environmental Impact Statement order~~ and the FERC order approving the CPCN. Each of these challenges ~~alleges~~alleged non-compliance on the part of federal and state permitting authorities and adverse ecological consequences if the Atlantic Coast Pipeline Project iswas permitted to proceed. Since December 2018, notable developments in these challenges ~~include~~included a stay in December 2018 issued by the U.S. Court of Appeals for the Fourth Circuit and the same ~~court's~~court’s July 2019 vacatur of the biological opinion and incidental take statement (which stay and subsequent vacatur halted most project construction activity), athe U.S. Court of Appeals for the Fourth Circuit ~~decision~~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~~Circuit’s remand to ~~U.S.~~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. ~~Atlantic Coast Pipeline is vigorously defending these challenges and coordinating with the federal and state authorities which are the direct parties to the challenges.~~ 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. In October 2019,~~crossing and in June 2020, the Supreme Court of the U.S. ~~agreed to hear~~ruled in favor of the ~~case. A ruling is expected no later than June 2020.~~ Atlantic Coast Pipeline, ~~is also evaluating possible legislative remedies~~reversing the lower court’s decision and remanding the case back to ~~this issue.~~

~~In anticipation of~~ the U.S. Court of Appeals for the Fourth ~~Circuit's vacatur~~Circuit.

The project also faced new and serious challenges from uncertainty related to NWP 12, specifically, from the decision of the ~~biological opinion and incidental take statement, Atlantic Coast Pipeline and~~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. ~~Fish~~issued an order allowing other new oil and ~~Wildlife Service commenced work~~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 ~~mid-May of 2019~~other federal circuit courts related to set the basis for a reissued biological opinion and incidental take statement. Atlantic Coast Pipeline continues coordinating and working with U.S. Fish and Wildlife Service and other parties in preparation for a reissuance of the biological opinion and incidental take statement.

~~Given the legal challenges described above and ongoing discussions with customers, project construction is expected to be completed by the end of 2021, with full in-service in early 2022.~~

~~The delays resulting from the legal challenges described above have impacted the cost and schedule~~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 ~~cost estimates are $7.3~~in June 2020, Atlantic Coast Pipeline has provided to Dominion Energy that it recorded net losses of $4.4 billion and $4.3 billion for the three and six months ended June 30, 2020, respectively, compared to ~~$7.8 billion, excluding financing costs. Given~~net income of $61 million and $114 million for the ~~status of current discussions with U.S. Fish~~three and ~~Wildlife Service regarding~~six months ended June 30, 2019, respectively, and that it did not record revenue for any period. As a new biological opinion and incidental take statement, as well as discussions with contractors regarding efficiencies which may be realized going forward, these estimates are under review and subject to upwardresult, Dominion Energy has recorded within earnings

~~pressure. Project construction activities, schedules~~(loss) from equity method investees a loss of $2.3 billion for both the three and ~~costs are also subject~~six months ended June 30, 2020 compared to ~~uncertainty due to permitting and/or work delays (including due to judicial or regulatory action), abnormal weather~~income of $29 million and $53 million for the three and six months ended June 30, 2019, respectively. At June 30, 2020, Dominion Energy has recorded a liability of $1.0 billion within other ~~conditions that could~~current liabilities in its Consolidated Balance Sheet, as a result ~~in cost or schedule modifications in the future, a suspension~~ of ~~AFUDC for~~its share of equity losses exceeding its investment which reflects Dominion Energy’s obligations on behalf of Atlantic Coast Pipeline ~~and/or impairment charges potentially~~related to its credit facility and AROs.

In October 2017, Dominion Energy entered into a guarantee agreement to support a portion of Atlantic Coast Pipeline’s obligation under a $3.4 billion revolving credit facility with a stated maturity date of October 2021. As of June 30, 2020, Atlantic Coast Pipeline had borrowed $1.8 billion against the revolving credit facility. In July 2020, the capacity of the revolving credit facility was reduced from $3.4 billion to $1.9 billion. Dominion Energy’s Consolidated Balance Sheets include a liability of $14 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, and $29 million and $128 million during the six months ended June 30, 2020 and 2019, respectively, to Atlantic Coast Pipeline. At June 30, 2020 and December 31, 2019, Dominion Energy had $5 million and $7 million, respectively, of contributions payable to Atlantic Coast Pipeline included within other current liabilities in the Consolidated Balance Sheets.

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 ~~cash flows,~~results of operations, financial position ~~and/~~or statement of cash flows. In connection with the sale of Dominion Energy’s gas transmission and storage operations to BHE discussed in Note 3, Dominion Energy expects to reflect the results of ~~operations.~~

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 discussed in Note 9 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

~~Other – Catalyst Old River Hydroelectric Limited Partnership~~Fowler Ridge

In September 2018, Dominion Energy completed the sale of its 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership and received proceeds of $91 million. The sale resulted in a gain of $87 million ($63 million after-tax), which is included in other income in Dominion Energy’s Consolidated Statement of Income.

~~Wrangler~~

~~In September 2019,~~July 2020, Dominion Energy entered into an agreement to ~~form Wrangler,~~sell its 50% noncontrolling partnership interest in Fowler Ridge to BP and to terminate a ~~partnership with Interstate Gas Supply, Inc. Wrangler will operate~~long-term power, capacity and renewable energy credit contract for a ~~nonregulated natural gas retail energy marketing business with~~net payment by Dominion Energy ~~contributing its nonregulated retail energy marketing operations and Interstate Gas Supply, Inc. contributing cash.~~

~~Dominion Energy expects the initial contribution, consisting~~ of ~~SCANA Energy Marketing, Inc.,~~$150 million. The transaction is expected to close in the ~~fourth~~third quarter of ~~2019,~~2020, subject to approval from the Georgia Public Service Commission and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. Dominion Energy will receive approximately $250 million in cash proceeds, subject to working capital adjustments, and expects to recognize a gain of approximately $135 million ($75 million after-tax), net of an approximately $70 million write-off of goodwill.

Dominion Energy will have a 20% noncontrolling ownership interest in Wrangler which will be accounted for as an equity method investment as Dominion Energy has the ability to exercise significant influence, but not control, over the investee.

In the third quarter of 2019, SCANA Energy Marketing, Inc.’s assets and liabilities to be contributed were classified as held for sale on the Consolidated Balance Sheet. SCANA Energy Marketing, Inc. is included in Dominion Energy’s Southeast Energy segment and is primarily comprised of intangible assets related to acquired customer lists in the SCANA Combination, trade accounts receivable, gas inventory and trade accounts payable.

~~Over the next three years,~~by FERC. Dominion Energy expects to ~~contribute its remaining nonregulated retail energy marketing operations to Wrangler under~~record a loss of approximately $220 million ($170 million after-tax), consisting of a loss on the ~~terms~~contract termination partially offset by a gain on the sale of the September 2019 agreement. As a result, Dominion Energy will receive additional cash consideration which will be based upon future financial performance. When these future contributions occur, Dominion Energy expects to retain a 20% noncontrolling ownership interest in Wrangler.partnership interest.

Dominion Energy Gas

~~Iroquois~~

Dominion Energy Gas’ equity earnings totaled ~~$13~~$23 million and ~~$18~~$22 million for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, ~~and 2018,~~ respectively. ~~Dominion Energy Gas recorded contributions of $2 million for the nine months ended September 30, 2019.~~ Dominion Energy Gas received distributions of ~~$27~~$25 million and ~~$20~~$30 million for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, the carrying amount of Dominion Energy Gas’ investment of ~~$79~~$310 million and ~~$91~~$312 million, respectively, exceeded its share of underlying equity in net assets by $8$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 million for the three months ended June 30, 2020 and 2019, respectively, and $37 million and $57 million for the six months ended June 30, 2020 and 2019, respectively, included in operating revenue in 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’ Consolidated Balance Sheets.

Note 11. Property, Plant and Equipment

~~Dominion Energy and Virginia Power~~

Acquisitions of Solar Projects

Other than the items discussed below, there have been no updates to acquisitions of solar projects by Dominion Energy or Virginia Power 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.

The following table presents acquisitions by Virginia Power of solar projects. Virginia Power 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

September 2017

June 2019

North Carolina

Gutenberg

$
142

September 2019

80

June 2018

February 2019

Virginia

Gloucester

37

April 2019

20

August 2018

March 2019

Virginia

Grasshopper

130

Expected 2020

80

August 2018

May 2019

North Carolina

Chestnut

130

Expected 2019

75

June 2019

June 2019

Virginia

Ft. Powhatan

270

Expected 2021

150

June 2019

August 2019

Virginia

Belcher

160

Expected 2020

88

August 2019

Pending

Virginia

Bedford

110

Expected 2021

70

October 2019

October 2019

Virginia

Maplewood

190

Expected 2022

120

Date Agreement Entered

Date Agreement Closed

Project Location

Project Name

Project Cost (millions)⁽¹⁾

Date of Commercial Operations

MW Capacity

May 2020

Virginia

Pumpkinseed

130

Expected 2022

(1)	Includes acquisition cost.

~~Dominion Energy~~

~~Acquisitions of Solar Projects~~

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

Date Agreement Closed

Project Location

Project Name

Project Cost (millions)⁽¹⁾

Date of Commercial Operations

MW Capacity

August 2019

Virginia

Greensville

130

Expected 2020

August 2019

Virginia

Myrtle

June 2020

August 2019

Virginia

Myrtle

Expected 2020

September 2019

South Carolina

Seabrook

105

Expected 2019

May 2020

South Carolina

Blackville

Expected 2020

May 2020

South Carolina

Denmark

Expected 2020

May 2020

Expected August 2020

South Carolina

Yemassee

Expected 2020

May 2020

Expected August 2020

South Carolina

Trask

Expected 2020

June 2020

Ohio

Hardin I

250

Expected 2020

150

July 2020

Virginia

Madison

125

Expected 2021

(1)	Includes acquisition cost.

In addition to the facilities discussed above, Dominion Energy ~~Gas~~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, Dominion Energy anticipates a total projected cost of approximately $35 million under these agreements with an associated aggregate generation capacity of 18 MW.

~~Assignment~~

Acquisition of ~~Shale Development Rights~~Gathering and Processing Assets

In ~~December 2013, Dominion Energy~~March 2020, Wexpro closed on agreements with natural gas producers to convey over time approximately 100,000 acres of Marcellus Shale development rights underneath several of its natural gas storage fields. The agreements provided for payments to Dominion Energy Gas, subject to customary adjustments, of up to approximately $200 million over a period of nine years, and an overriding royalty interest in gas produced from the acreage. In August 2017, Dominion Energy Gas and a natural gas producer signed an amendment to the agreement, which included the finalization of contractual matters on previous conveyances, the conveyance of Dominion Energy Gas’ remaining 68% interest in approximately 70,000 acres and the elimination of Dominion Energy Gas’ overriding royalty interest in gas produced from all acreage. Dominion Energy Gas received total consideration of $130 million, with $65 million received in the fourth quarter of 2017 and $65 million received in September 2018 in connection with the final conveyance. In September 2018, Dominion Energy Gas recognized a $65 million ($47 million after-tax) gain included in gains on sales of assets in Dominion Energy Gas’ Consolidated Statements of Income associated with the final conveyance of acreage.

~~In November 2014, Dominion Energy Gas closed~~ an agreement with a natural gas ~~producer~~gathering systems operator to ~~convey over time approximately 24,000 acres of Marcellus Shale development rights underneath 1 of its~~purchase existing natural gas ~~storage fields. In January 2018, Dominion Energy Gas~~gathering systems including pipelines, compressors and ~~the~~dehydration equipment for total consideration of $38 million. These facilities gather natural gas ~~producer closed on an amendment to the agreement, which included the conveyance of Dominion Energy Gas’ remaining 50% interest~~ in ~~approximately 18,000 acres~~Colorado, Utah and the elimination of Dominion Energy Gas’ overriding royalty interest in gas produced from all acreage. In February 2018, Dominion Energy Gas received proceeds of $28 million, resulting in an approximately $28 million ($20 million after-tax) gain recorded in gains on sales of assets in Dominion Energy Gas’ Consolidated Statements of Income.

In March 2018, Dominion Energy Gas closed an agreement with a natural gas producer to convey approximately 11,000 acres of Utica and Point Pleasant Shale development rights underneath 1 of its natural gas storage fields. The agreement provided for a payment to Dominion Energy Gas, subject to customary adjustments, of $16 million. In March 2018, Dominion Energy Gas received cash proceeds of $16 million associated with the conveyance of the acreage, resulting in a $16 million ($12 million after-tax) gain recorded in gains on sales of assets in Dominion Energy Gas’ Consolidated Statements of Income.

In June 2018, Dominion Energy Gas closed an amendment to an agreement with a natural gas producer for the elimination of Dominion Energy Gas’ overriding royalty interest in gas produced from approximately 9,000 acres of Marcellus Shale development rights underneath 1 of its natural gas storage fields previously conveyed in December 2013. In June 2018, Dominion Energy Gas received proceeds of $6 million associated with the transaction, resulting in a $6 million ($4 million after-tax) gain recorded in ~~gains on sales of assets~~ ~~in Dominion Energy Gas’ Consolidated Statements of Income.~~Wyoming.

Note 12. Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	September 30, 2019		December 31, 2018		June 30, 2020		December 31, 2019
(millions)
Dominion Energy
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	78	$	174	$	—	$	48
Deferred project costs and DSM programs for gas utilities⁽²⁾		29		17		49		21
Unrecovered gas costs⁽³⁾		118		14		42		102
Deferred rate adjustment clause costs for Virginia electric utility⁽⁴⁾⁽⁵⁾		226		78		58		109
Deferred nuclear refueling outage costs⁽⁶⁾		50		69		60		68
NND Project costs⁽⁷⁾		138		—		138		138
PJM transmission rates⁽⁸⁾		69		45		21		121
Other		258		99		248		272
Regulatory assets-current		966		496		616		879
Deferred cost of fuel used in electric generation⁽¹⁾		—		83
Unrecognized pension and other postretirement benefit costs⁽⁹⁾		1,331		1,497
Deferred rate adjustment clause costs for Virginia electric utility^(4)(5)(10)		88		230
Pension and other postretirement benefit costs⁽⁹⁾						1,392		1,431
Deferred rate adjustment clause costs for Virginia electric utility^{(4)(5)(10)(11)}						409		235
PJM transmission rates⁽⁸⁾						154		85
Deferred project costs for gas utilities⁽²⁾		482		335		557		521
PJM transmission rates⁽⁸⁾		169		192
Interest rate hedges⁽¹¹⁾		897		184
AROs and related funding⁽¹²⁾		330		—
Cost of reacquired debt^(13)(14)		283		3
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⁾		2,537		—		2,434		2,503
Ash pond and landfill closure costs⁽¹⁵⁾		1,003		27		2,139		1,016
Other		549		125		487		582
Regulatory assets-noncurrent		7,669		2,676		9,438		7,687
Total regulatory assets	$	8,635	$	3,172	$	10,054	$	8,566
Regulatory liabilities:
Deferred cost of fuel used in electric generation⁽¹⁾					$	111	$	—
Provision for future cost of removal and AROs⁽¹⁶⁾	$	117	$	117		142		142
Reserve for refunds and rate credits to electric utility customers⁽¹⁷⁾		215		71		134		143
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁸⁾		2		104		35		4
Income taxes refundable through future rates⁽¹⁹⁾		82		—		140		77
Monetization of guarantee settlement⁽²⁰⁾		67		—		67		67
Other		64		64		120		64
Regulatory liabilities-current		547		356		749		497
Income taxes refundable through future rates⁽¹⁹⁾		5,007		4,071		4,988		5,088
Provision for future cost of removal and AROs⁽¹⁶⁾		2,315		1,409		2,253		2,302
Nuclear decommissioning trust⁽²¹⁾		1,354		1,070		1,372		1,471
Monetization of guarantee settlement⁽²⁰⁾		987		—		936		970
Reserve for refunds and rate credits to electric utility customers⁽¹⁷⁾		707		—		588		656
Overrecovered other postretirement benefit costs⁽²²⁾		151		120		212		189
Other		405		170		331		325
Regulatory liabilities-noncurrent		10,926		6,840		10,680		11,001
Total regulatory liabilities	$	11,473	$	7,196	$	11,429	$	11,498

(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. 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)

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 for more information.

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

(9)	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)

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 ~~September~~June 30, ~~2019.~~2020.

~~(12)~~(13)

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 ~~V.C.~~ Summer, ~~nuclear power station,~~ and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately ~~106 years.~~

~~(13)~~

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 26105 years ~~as of September 30, 2019.~~

~~(14)~~

During 2019, DESC purchased certain of its first mortgage bonds as discussed in Note 17. As a result of these transactions, DESC incurred net costs, including write-offs of unamortized discount, premium and debt issuance costs, of $270 million.

(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)

Primarily reflects legislation enacted in Virginia in March 2019 which requires any CCR unit located at certain Virginia Power stations to be closed by removing the CCRs to an approved landfill or through recycling for beneficial reuse. Subject to approval by the Virginia Commission, amounts are expected to be collected over a period between 15 and 18 years commencing no earlier than 2021. Virginia Power is entitled to collect carrying costs once expenditures have been made. See Note 1823 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019 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)	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)

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 and Virginia legislation enacted in March 2018 that required one-time rate credits of certain amounts to utility customers in Virginia.~~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, ~~2018 and Note 3~~2019 for more information.

(18)

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, ~~2018 and Note 13~~2019 for more information.

(19)

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)

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 ~~additional~~the year ended December 31, 2019 for more information.

(21)

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

	September 30, 2019		December 31, 2018		June 30, 2020		December 31, 2019
(millions)
Virginia Power
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	78	$	174	$	—	$	48
Deferred rate adjustment clause costs⁽²⁾⁽³⁾		226		78		58		109
Deferred nuclear refueling outage costs⁽⁴⁾		50		69		60		68
PJM transmission rates⁽⁵⁾		69		45		21		121
Other		46		58		58		87
Regulatory assets-current⁽⁶⁾		469		424		197		433
Deferred rate adjustment clause costs^(2)(3)(7)		88		230
Deferred rate adjustment clause costs^(2)(3)(6)(7)						409		235
PJM transmission rates⁽⁵⁾		169		192		154		85
Interest rate hedges⁽⁸⁾		555		151		956		404
Deferred cost of fuel used in electric generation⁽¹⁾		—		83
Ash pond and landfill closure costs⁽⁹⁾		1,003		27		2,139		1,016
Other		102		54		122		123
Regulatory assets-noncurrent		1,917		737		3,780		1,863
Total regulatory assets	$	2,386	$	1,161	$	3,977	$	2,296
Regulatory liabilities:
Deferred cost of fuel used in electric generation⁽¹⁾					$	111	$	—
Provision for future cost of removal⁽¹⁰⁾	$	92	$	92		103		103
Cost-of-service impact of 2017 Tax Reform Act⁽¹¹⁾		2		95
Reserve for rate credits to electric utility customers⁽¹²⁾		—		71
Income taxes refundable through future rates⁽¹³⁾		74		—
Income taxes refundable through future rates⁽¹¹⁾						54		54
Other		12		41		28		10
Regulatory liabilities-current		180		299		296		167
Income taxes refundable through future rates⁽¹³⁾		2,405		2,579
Nuclear decommissioning trust⁽¹⁴⁾		1,354		1,070
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⁾		1,056		940		993		1,054
Deferred cost of fuel used in electric generation⁽¹⁾						3		30
Other		163		58		161		81
Regulatory liabilities-noncurrent		4,978		4,647		4,954		5,074
Total regulatory liabilities	$	5,158	$	4,946	$	5,250	$	5,241

(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. See Note 13 for more information.

(3)

(4)	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.

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

(6)	~~Current regulatory assets are presented in other current assets in Virginia Power’s Consolidated Balance Sheets.~~

~~(7)~~

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.

(7)	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.

(8)

(9)

Primarily reflects legislation enacted in Virginia in March 2019 which requires any CCR unit 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 are expected to be collected over a period between 15 and 18 years commencing no earlier than 2021. Virginia Power is entitled to collect carrying costs once expenditures have been made. See Note 1823 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2019 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)	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)

Balance refundable to customers related to the decrease in revenue requirements for recovery of income taxes at regulated electric generation and distribution operations. See Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018 and Note 13 for more information.

~~(12)~~

Charge associated with Virginia legislation enacted in March 2018 that required one-time rate credits of certain amounts to utility customers. See Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018 for more information.

~~(13)~~

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.

~~(14)~~

(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.

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.

September 30, 2019

December 31, 2018

(millions)

Dominion Energy Gas

Regulatory assets:

Deferred project costs⁽¹⁾

$
23

$
18

PIPP⁽²⁾

9

—

Unrecovered gas costs⁽³⁾

4

9

Other

6

2

Regulatory assets-current

42

29

Unrecognized pension and other postretirement benefit costs⁽⁴⁾

286

392

Deferred project costs⁽¹⁾

393

334

Other

4

1

Regulatory assets-noncurrent⁽⁵⁾

683

727

Total regulatory assets

$
725

$
756

Regulatory liabilities:

Provision for future cost of removal and AROs⁽⁶⁾

$
14

$
14

PIPP⁽²⁾

—

3

Other

9

4

Regulatory liabilities-current⁽⁷⁾

23

21

Income taxes refundable through future rates⁽⁸⁾

1,000

1,011

Provision for future cost of removal and AROs⁽⁶⁾

152

158

Overrecovered other postretirement benefit costs⁽⁹⁾

110

92

Other

37

24

Regulatory liabilities-noncurrent

1,299

1,285

Total regulatory liabilities

$
1,322

$
1,306

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

~~(2)~~

Under PIPP, eligible customers can make reduced payments based on their ability to pay. The difference between the customer’s total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018 for more information.

~~(3)~~

Reflects unrecovered or overrecovered gas costs at regulated gas operations, which are recovered or refunded through filings with FERC.

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

(3)

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 ~~applicable regulatory authority.~~life of the related debt, which has a weighted average useful life of approximately 22 years.

(4)	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 Gas' rate-regulated subsidiaries.

~~(5)~~

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

~~(6)~~(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.

~~(7)~~(6)

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

~~(8)~~(7)

~~(9)~~(8)

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

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

At ~~September~~June 30, ~~2019,~~2020, Dominion Energy, Virginia Power and Dominion Energy Gas’ regulatory assets include ~~$2.4~~$4.8 billion, ~~$1.3~~$3.4 billion and ~~$115~~$44 million, 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 - Electric~~

Under the Federal Power Act, FERC regulates wholesale sales and transmission of electricity in interstate commerce by public utilities. Virginia Power purchases and, under its market based rate authority, sells electricity in the PJM wholesale market and to wholesale purchasers in Virginia and North Carolina. DESC sells electricity to wholesale purchasers in its balancing authority area under its electric cost based tariff and to wholesale purchasers outside of its balancing authority area under its market based rate authority. Dominion Energy’s merchant generators sell electricity in the PJM, CAISO and ISO-NE wholesale markets, and to wholesale purchasers in the states of Virginia, North Carolina, Indiana, Connecticut, Tennessee, Georgia, California, South Carolina and Utah, under Dominion Energy’s market-based sales tariffs authorized by FERC or pursuant to FERC authority to sell as a qualified facility. In addition, Virginia Power has FERC approval of a tariff to sell wholesale power at capped rates based on its embedded cost of generation. This cost-based sales tariff could be used to sell to loads within or outside Virginia Power’s service territory. Any such sales would be voluntary.

~~Rates~~

In April 2008, FERC granted an application for Virginia Power’s electric transmission operations to establish a forward-looking formula rate mechanism that updates transmission rates on an annual basis and approved an ROE effective as of January 1, 2008. The formula rate is designed to recover the expected revenue requirement for each calendar year and is updated based on actual costs. The FERC-approved formula method, which is based on projected costs, allows Virginia Power to earn a current return on its investment in electric transmission infrastructure.

~~In March 2010, ODEC and North Carolina Electric Membership Corporation~~ filed a complaint with FERC against Virginia Power claiming, among other issues, that the incremental costs of undergrounding certain transmission line projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power’s transmission formula rate. A settlement of the other issues raised in the complaint was approved by FERC in May 2012.

In March 2014, FERC issued an order excluding from Virginia Power’s transmission rates for wholesale transmission customers located outside Virginia the incremental costs of undergrounding certain transmission line projects. FERC found it is not just and reasonable for non-Virginia wholesale transmission customers to be allocated the incremental costs of undergrounding the facilities because the projects are a direct result of Virginia legislation and Virginia Commission pilot programs intended to benefit the citizens of Virginia. The order is retroactively effective as of March 2010 and will cause the reallocation of the costs charged to wholesale transmission customers with loads outside Virginia to wholesale transmission customers with loads in Virginia. FERC determined that there was not sufficient evidence on the record to determine the magnitude of the underground increment and held a hearing to determine the appropriate amount of undergrounding cost to be allocated to each wholesale transmission customer in Virginia.

In October 2017, FERC issued an order determining the calculation of the incremental costs of undergrounding the transmission projects and affirming that the costs are to be recovered from the wholesale transmission customers with loads located in Virginia. FERC directed Virginia Power to rebill all wholesale transmission customers retroactively to March 2010 within 30 days of when the proceeding becomes final and no longer subject to rehearing. In November 2017, Virginia Power, North Carolina Electric Membership Corporation and the wholesale transmission customers filed petitions for rehearing. In July 2018, FERC denied the rehearing requests related to the October 2017 order determining the calculation of the undergrounding costs. Several parties have appealed FERC’s decision to the U.S. Court of Appeals for the D.C. Circuit. This matter is pending. While Virginia Power cannot predict the outcome of the matter, it is not expected to have a material effect on results of operations.

In January 2019, FERC issued an order denying PJM’s request to waive certain provisions of the PJM Tariff regarding the liquidation of a portfolio of FTRs owned by GreenHat who had defaulted on its financial obligations. As a result of FERC’s order, PJM is required to use the existing tariff provisions to liquidate GreenHat’s FTR portfolio and allocate the resulting costs to PJM members. In February 2019, PJM filed a request for clarification and rehearing with FERC. Also in February 2019, Virginia Power and certain other PJM members filed a request for rehearing with FERC. In June 2019, FERC established a hearing and settlement proceedings to address the issues raised in PJM’s request for clarification and rehearing. In October 2019, PJM submitted a settlement offer to FERC which is pending approval. Based on the terms of the proposed settlement, the impact to Virginia Power is expected to be immaterial.

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 recognized a charge of $129 million ($94 million after-tax) recorded primarily within impairment of assets and other charges in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income during the second quarter of 2018 for a disallowance of plant, originally established beginning in 2012, in anticipation of resolution of one matter with FERC. 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 ~~Notes 3 and~~Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~

In January 2019, Virginia Power filed updated testimony in response to the Virginia Commission’s September 2018 order with a proposed annual revenue reduction of approximately $171 million. Additionally, Virginia Power proposed to issue a one-time bill credit to customers within 90 days of this effective date, to true-up the difference between the final revenue reduction for the period January 1, 2018 through March 31, 2019 and the $125 million interim rate reduction implemented on July 1, 2018. In March 2019, the Virginia Commission issued an order approving an annual revenue reduction of approximately $183 million effective April 2019 and ordered Virginia Power to implement the one-time customer credit on or before July 1, 2019. ~~In the second quarter of 2019, Virginia Power refunded to customers $132 million.~~

In October 2018, the North Carolina Commission issued an order requesting companies file to reduce base rates expeditiously. Virginia Power made its compliance filing in October 2018 and submitted an annual base rate revenue decrease of approximately $14 million effective in early 2019. Virginia Power also proposed to issue a one-time bill credit in early 2019 for its 2018 tax savings collected provisionally from customers. The order allowed for the disposition of excess deferred income taxes to be deferred for consideration until the utilities’ next base rate case, but no longer than 3 years, and initiated a quarterly reporting requirement for such deferred amounts. In March 2019, the North Carolina Commission issued an order approving Virginia Power’s proposed annual base rate revenue decrease and one-time bill credit. In the second quarter of 2019, Virginia Power refunded to customers $13 million.

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 ~~May 2019,~~March 2020, the Utah Commission issued an order approving Questar Gas’ proposal to refund the ~~2018~~January 2019 through February 2020 amortization of excess deferred income taxes over ~~twelve~~12 months beginning in June ~~2019. The matter with~~2020. In April 2020, at the request of the Wyoming Commission, ~~is pending.~~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. ~~This case is pending.~~

In ~~March 2018, FERC announced actions~~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 ~~address~~which the excess deferred income ~~tax allowance component of regulated entities’ cost-of-service~~taxes relate. In addition, East Ohio will reduce rates ~~as a result of~~approximately $19 million per year to account for the 2017 Tax Reform ~~Act. FERC required all interstate natural gas pipelines~~Act’s impact on its equity return component of rates charged to ~~make a one-time informational filing with FERC on Form 501-G to provide financial information to allow FERC and other interested parties to analyze~~customers. A tax savings credit, which passes through the ~~impacts of~~reduction in the ~~changes in tax law. The actions also included the reversal of FERC’s policy allowing master limited partnerships to recover an~~federal income tax ~~allowance~~rate under the 2017 Tax Reform Act to customers in ~~cost-of-service rates and requiring other pass-through entities to justify~~accordance with the ~~inclusion of an income tax allowance.~~

~~During 2018, Dominion Energy’s FERC-regulated pipelines, including those accounted for as equity method investments, filed~~settlement agreement approved by the ~~Form 501-G~~Ohio Commission, became effective with ~~FERC. Dominion Energy Overthrust Pipeline, LLC, White River Hub, Dominion Energy Questar Pipeline, DETI, DECG, Cove Point and Iroquois have reached resolution through a FERC waiver or FERC terminating~~ the ~~501-G proceeding, or through settlement, which did not result~~first billing cycle in ~~a material impact to results of operations, financial condition and/or cash flows of Dominion Energy or Dominion Energy Gas.~~

April 2020.

Other Regulatory Matters

Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in ~~Notes 3 and~~Note 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019.

Virginia Regulation

Virginia 2020 Legislation

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 for Virginia Power with a mandatory program setting annual renewable energy portfolio standard requirements based on the percentage of total electric energy sold by 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 to 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 ~~Note 13~~modified regulatory framework through rate adjustment clauses, rates for generation and distribution services or Virginia Power’s fuel factor, as approved by the Virginia Commission. Costs allocated to the ~~Consolidated Financial Statements~~North Carolina jurisdiction will be recovered, subject to approval by the North Carolina Commission, in accordance with the ~~Companies’ Quarterly Reports~~existing regulatory framework.

In May 2020 and July 2020, Virginia Power entered into and closed on ~~Form 10-Q~~ 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 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 ~~quarters ended March 31, 2019 and June 30, 2019.~~

costs associated with the recovery of certain renewable generation facilities in Virginia ~~Regulation~~by the end of 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 ~~is $511~~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 to construct Sadler Solar, which is ~~$83 million. This matter~~estimated to cost approximately $146 million, excluding financing costs. Sadler Solar is ~~pending.~~expected to commence commercial operations, subject to regulatory approvals associated with the project, in 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. 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 ~~May 2019,~~February 2020, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated ~~$1.5~~$1.2 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, ~~2019~~2020 and a projected over-recovery of approximately $81 million for the ~~projected~~prior year balance as of June 30, ~~2019 underrecovered balance of $124 million.~~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, the Virginia Commission approved the interim rates. Virginia Power’s proposed fuel rate ~~represented~~represents a fuel revenue decrease of ~~$192~~approximately $393 million when applied to projected kilowatt-hour sales for the ~~period July~~rate year beginning May 1, ~~2019 to~~2020. In June 30, 2020. Subsequently in May 2019, Virginia Power revised its fuel factor filing to reduce the projected June 30, 2019 underrecovered balance to $107 million and a fuel revenue decrease of $254 million. In August 2019,2020, 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.

Rate Adjustment Clauses

Below is a discussion of significant riders associated with various Virginia ~~Power’s fuel rate.~~Power projects:

~~Battery Storage Pilot~~

•

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 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. This matter is pending.

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)

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

)

Rider GV

June 2020

Pending

April 2021

154

Rider R

June 2020

Pending

April 2021

Rider S

June 2020

Pending

April 2021

194

)

Rider W

June 2020

Pending

April 2021

120

Rider US-3

July 2020

Pending

June 2021

Rider US-4

July 2020

Pending

June 2021

Electric Transmission Projects

In ~~August~~December 2019, Virginia Power filed an application with the Virginia Commission ~~to participate in~~for a ~~pilot program for electric power storage batteries, which includes three projects for deployment of battery energy storage systems. Virginia Power also requested an amended~~ CPCN to construct a new Evergreen Mills switching station and ~~operate a battery energy storage system at Scott Solar. The projects are~~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 ~~$35~~$30 million. ~~These matters are pending.~~

~~Rate Adjustment Clauses~~

In ~~December 2018, Virginia Power filed a petition requesting approval of Rider E and proposed a $114 million total revenue requirement for the rate year beginning November 1, 2019. In August 2019,~~May 2020, the Virginia Commission issued an order approving in part and denying in part the petition. As a result, Virginia Power recorded a $21 million ($16 million after-tax) charge in impairment of assets and other charges in the Consolidated Statements of Income for the three and nine months ended September 30, 2019 to write-off certain disallowed environmental property, plant and equipment and regulatory assets. In August 2019, the Virginia Commission granted Virginia Power’s petition for reconsideration of the disallowed amount and stayed the order issued earlier in August 2019. In October 2019, theThe Virginia Commission approved Virginia Power’s request to ~~implement a total revenue requirement of $104 million, subject to true-up, pending resolution of~~construct the ~~petition for reconsideration. This matter is pending.~~

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 October 2019, The Virginia Commission approved Virginia Power’s proposed fourth phase of conversions totaling $123 million and a total $52 million revenue requirement for the rate year beginning February 1, 2020 for continuing recovery of the previously approved phase conversionsnew Evergreen Mills switching station and the ~~proposed fourth phase conversions.~~

~~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)

Rider BW

October 2019

Pending

September 2020

$
120

$
1

Rider US-2

October 2019

Pending

September 2020

10

(5
)

~~Electric Transmission Projects~~

~~In November 2013, the Virginia Commission issued an order granting Virginia Power a CPCN to construct approximately 7 miles of~~ new ~~overhead 500~~230 kV double circuit transmission line from the existing ~~Surry switching station in Surry County to~~Brambleton-Yardley Ridge line with a ~~new Skiffes Creek switching station in James City County, and approximately 20 miles~~total estimated cost of new 230 kV transmission line in James City County, York County, and the City of Newport News from the proposed new Skiffes Creek switching station to Virginia Power’s existing Whealton substation in the City of Hampton. In February 2019, the transmission line project was placed into service. In March 2019, the U.S. Court of Appeals for the D.C. Circuit issued an order vacating the permit from the U.S. Army Corps of Engineers issued in July 2017 and ordered the U.S. Army Corps of Engineers to do a full environmental impact study of the project. In April 2019, Virginia Power and the U.S. Army Corps of Engineers filed petitions for rehearing with the U.S. Court of Appeals for the D.C. Circuit, asking that the permit from the U.S. Army Corps of Engineers remain in effect while an environmental impact study is performed. In May 2019, the U.S. Court of Appeals for the D.C. Circuit denied the request for rehearing and ordered the U.S. District Court for the D.C. Circuit to consider and issue a ruling on whether the permit should be vacated during the U.S. Army Corps of Engineers’ preparation of an environmental impact statement. This matter is pending. $25 million.

Additional Virginia Power electric transmission projects approved orand 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 the Glebe substation and relocate
   and operate in Arlington County, Virginia and the City
   of Alexandria, Virginia existing overhead line
   underground

March 2019

September 2019

230 kV

<1

$
125

Rebuild and operate five segments between the Loudoun
   and Ox substations

August 2019

Pending

230 kV

19

70

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

North Carolina Regulation

North Carolina Base Rate Case

In March 2019, Virginia Power filed its base rate case and schedules with the North Carolina Commission. Virginia Power proposed a non-fuel, base rate increase of $27 million effective November 1, 2019 on an interim basis subject to refund, with any permanent rates ordered by the North Carolina Commission effective January 1, 2020. The base rate increase was proposed to recover the significant investments in generation, transmission and distribution infrastructure for the benefit of North Carolina customers. Virginia Power presented an earned return of 7.52% based upon a fully-adjusted test period, compared to its 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. This matter is pending.

Pipeline Integrity and Safety Program

The North Carolina ~~Fuel Filing~~

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 ~~August 2019, Virginia Power submitted its annual filing to~~February 2020, the North Carolina Commission approved PSNC’s request to ~~adjust~~increase the ~~fuel component~~integrity management annual revenue requirement to $28 million, an increase of $7 million over its ~~electric rates. Virginia Power proposed a total $18 million decrease to the fuel component of its electric rates for the rate year beginning February 1,~~previous filing, effective March 2020. ~~This matter is pending.~~

South Carolina Regulation

South Carolina Electric Base Rate Case

Pursuant to the SCANA Merger Approval Order, DESC will not file an application for a general rate case with the South Carolina Commission with a requested effective date for new rates earlier than January 2021. In April 2020, the South Carolina Commission issued an order vacating the portion of the SCANA Merger Approval Order requiring that new retail electric rates be implemented by January 1, 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.

DSM Programs

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

Cost of Fuel

In February 2020, DESC filed a proposal with the South Carolina Commission to decrease the total fuel cost component of retail electric rates. DESC’s proposed decrease would reduce annual base fuel component recoveries by $44 million and is projected to return to customers the existing over-collected balance while recovering DESC’s current base fuel costs over the 12-month period beginning with the first billing cycle of May 2020. In addition, DESC proposed an increase to its variable environmental and distributed energy resource components. In April 2020, 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 ~~2019,~~2020, the South Carolina Commission approved the filing.

Natural Gas Rates

In June 2020, DESC filed with the South Carolina Commission its monitoring report for the 12-month period ended March 31, ~~2019~~2020 with a total revenue requirement of ~~$437~~$409 million. This represents a $7$9 million overall annual increase to its natural gas rates under the terms

of the Natural Gas Rate Stabilization Act effective ~~for the rate year beginning November 2019. In October 2019, the South Carolina Commission approved a total revenue requirement of $436 million effective~~ with the first billing cycle of November ~~2019.~~2020. This matter is pending.

Ohio Regulation

~~UEX Rider~~PIR Program

In 2008, East Ohio ~~has approval for a UEX rider through which it recovers the bad debt expense~~began PIR, aimed at replacing approximately 25% 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.~~its pipeline system. In ~~July 2019,~~April 2020, the Ohio Commission approved East Ohio’s application ~~requesting approval~~to adjust the PIR recovery for 2019 costs. The filing reflects gross plant investment for 2019 of ~~its UEX rider to reflect recovery~~$209 million, cumulative gross plant investment of ~~under-recovered accumulated bad debt expense~~$1.8 billion and an annual revenue requirement of approximately $3 million as of March 31, 2019, and recovery of prospective net bad debt expense projected to total approximately $15 million for the twelve-month period from April 2019 to March 2020 for the rate year beginning August 1, 2019.$218 million.

West Virginia Regulation

PREP

In May ~~2019,~~2020, Hope filed a PREP application with the West Virginia Commission requesting approval to recover PREP costs related to ~~$29~~$39 million and ~~$39~~$54 million of projected capital investment for ~~2019~~2020 and ~~2020,~~2021, respectively. The application also includes a true-up of PREP costs related to the ~~2018~~2019 actual capital investment of ~~$30~~$27 million and sets forth ~~$10~~$13 million of annual PREP costs to be recovered in proposed rates effective November 1, ~~2019. In October 2019, the West Virginia Commission approved PREP rates effective November 1, 2019.~~2020. This matter is pending.

~~Utah~~Wyoming Regulation

Wyoming Base Rate Case

In ~~April~~November 2019, Questar Gas filed ~~a request~~its base rate case and schedules with the ~~Utah~~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 Wyoming Commission ~~for pre-approval to construct~~approved a base rate increase of $2 million annually, with rates effective September 1, 2020. This revenue requirement increase is based on an ~~LNG storage facility with a liquefaction rate~~approved ROE of ~~8.2 million cubic feet per day. In October 2019, the Utah Commission granted pre-approval to construct the LNG storage facility.~~9.35%.

FERC – Gas

Cove Point

In ~~June 2015, Cove Point executed 2 binding precedent agreements for~~January 2020, pursuant to the approximately $150 million Eastern Market Access Project. In January 2018, Cove Point received FERC authorization to construct and operate the project facilities. In October 2018, Cove Point announced it was evaluating alternatives toterms of a proposed Charles County, Maryland compressor station that was initially part of this project and in December 2018, after working with project customers for alternative solutions, decided not to pursue further construction at this location resulting in a revised project estimate of approximately $45 million and a write-off of $37 million ($28 million after-tax). In May 2019,previous settlement, Cove Point filed ~~an application~~a general rate case for ~~an amendment~~its FERC-jurisdictional services, with proposed rates to ~~vacate its FERC authorization for the Charles County, Maryland compressor station and revised its project scope. In August 2019,~~be effective March 1, 2020. Cove Point ~~received~~proposed an annual cost-of-service of approximately $182 million. In February 2020, FERC ~~authorization and~~approved suspending the ~~Eastern Market Access Project commenced commercial operations~~changes in ~~September 2019.~~rates for five months following the proposed effective date, until August 1, 2020, subject to refund.

In ~~connection with the Eastern Market Access Project, in August 2019,~~February 2020, Cove Point filed to update its annual electric power cost adjustment requesting FERC approval to recover $25 million, representing an increase of $1 million from the adjustment approved in March 2019. FERC approved the adjustment in August 2019.

~~DETI~~

~~In September 2019, DETI submitted its annual transportation cost rate adjustment to FERC requesting approval to recover $38 million. Also in September 2019, DETI~~ 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. ~~In October 2019,~~ FERC approved ~~these adjustments.~~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.

Note 14. ~~Asset Retirement Obligations~~Leases

~~AROs represent obligations that result from laws, statutes, contracts and regulations related to~~Other than the ~~eventual retirement of certain of~~items discussed below, there have been no significant changes regarding the Companies’ long-lived assets. Dominion Energy and Virginia Power’s AROs are primarily associated with the decommissioning of their nuclear generation facilities and ash pond and landfill closures. Dominion Energy Gas’ AROs primarily include plugging and abandonment of gas and oil wells and the interim retirement of natural gas gathering, transmission, distribution and storage pipeline components.

~~The Companies have also identified, but not recognized, AROs related~~leases as described in Note 15 to the retirement of Dominion Energy’s LNG facility, Dominion Energy and Dominion Energy Gas’ storage wells in their underground natural gas storage network, certain Virginia Power electric transmission and distribution assets located on property with easements, rights of way, franchises and lease agreements, Virginia Power’s hydroelectric generation facilities and the abatement of certain asbestos not expected to be disturbed in Dominion Energy and Virginia Power’s generation facilities. The Companies currently do not have sufficient information to estimate a reasonable range of expected retirement dates for any of these assets since the economic lives of these assets can be extended indefinitely through regular repair and maintenance and they currently have no plans to retire or dispose of any of these assets. As a result, a settlement date is not determinable for these assets and AROs for these assets will not be reflected in the Consolidated Financial Statements ~~until sufficient information becomes available to determine a reasonable estimate of~~in the ~~fair value of~~Companies’ Annual Report on Form 10-K for the activities to be performed. The Companies continue to monitor operational and strategic developments to identify if sufficient information exists to reasonably estimate a retirement date for these assets. The changes to AROs during 2019 were as follows:year ended December 31, 2019.

Amount

(millions)

Dominion Energy

AROs at December 31, 2018⁽¹⁾
$

2,532

Obligations incurred during the period⁽²⁾

2,404

Obligations settled during the period

(100
)
AROs acquired in the SCANA Combination

577

Revisions in estimated cash flows⁽²⁾

(229
)
Accretion

153

AROs at September 30, 2019⁽¹⁾
$

5,337

Virginia Power

AROs at December 31, 2018⁽³⁾
$

1,445

Obligations incurred during the period⁽²⁾

2,403

Obligations settled during the period

(60
)
Revisions in estimated cash flows⁽²⁾

(202
)
Accretion

94

AROs at September 30, 2019⁽³⁾
$

3,680

Dominion Energy Gas

AROs at December 31, 2018⁽⁴⁾
$
167

Obligations settled during the period

(6
)
Revisions in estimated cash flows

(26
)
Accretion

7

AROs at September 30, 2019⁽⁴⁾
$
142

~~(1)~~

~~Includes $282 million and $317 million reported in other current liabilities at December 31, 2018 and September 30, 2019, respectively.~~

~~(2)~~

~~Primarily related to future ash pond and landfill closure costs at certain utility generation facilities. See Note 18 for further information.~~

~~(3)~~

~~Includes $245 million and $262 million reported in other current liabilities at December 31, 2018 and September 30, 2019, respectively.~~

~~(4)~~

Includes $153 million and $134 million reported in other deferred credits and other liabilities, with the remainder recorded in other current liabilities, at December 31, 2018 and September 30, 2019, respectively.

Dominion Energy and Virginia Power have established trusts dedicated to funding the future decommissioning of their nuclear plants. At September 30, 2019 and December 31, 2018, the aggregate fair value of Dominion Energy’s trusts, consisting primarily of equity and debt securities, totaled $5.9 billion and $4.9 billion, respectively. At September 30, 2019 and December 31, 2018, the aggregate fair value of Virginia Power’s trusts, consisting primarily of debt and equity securities, totaled $2.7 billion and $2.4 billion, respectively.

~~Note 15. Leases~~

~~At September 30, 2019, the Companies had the following lease assets and liabilities recorded in the Consolidated Balance Sheets:~~

September 30, 2019

(millions)

Dominion Energy

Lease assets:

Operating lease assets

$
455

Finance lease assets⁽¹⁾

159

Total lease assets

$
614

Lease liabilities:

Operating lease liabilities⁽²⁾

$
58

Finance lease liabilities⁽³⁾

30

Total lease liabilities - current

88

Operating lease liabilities

394

Finance lease liabilities⁽⁴⁾

132

Total lease liabilities - noncurrent

526

Total lease liabilities

$
614

Virginia Power

Operating lease assets

$
184

Finance lease assets⁽¹⁾

15

Total lease assets

$
199

Lease liabilities:

Operating lease liabilities⁽²⁾

$
30

Finance lease liabilities⁽³⁾

3

Total lease liabilities - current

33

Operating lease liabilities

152

Finance lease liabilities⁽⁴⁾

11

Total lease liabilities - noncurrent

163

Total lease liabilities

$
196

Dominion Energy Gas

Operating lease assets

$
56

Finance lease assets⁽¹⁾

10

Total lease assets

$
66

Lease liabilities:

Operating lease liabilities⁽²⁾

$
12

Finance lease liabilities⁽³⁾

2

Total lease liabilities - current

14

Operating lease liabilities

44

Finance lease liabilities⁽⁴⁾

8

Total lease liabilities - noncurrent

52

Total lease liabilities

$
66

~~(1)~~

~~Included in property, plant and equipment in the Companies’ Consolidated Balance Sheets, net of $39 million, $~~3 ~~million and $~~2 ~~million of accumulated amortization at Dominion Energy, Virginia Power and Dominion Energy Gas, respectively, at September 30, 2019.~~

~~(2)~~

~~Included in other current liabilities in the Companies’ Consolidated Balance Sheets.~~

~~(3)~~

~~Included in securities due within one year in the Companies’ Consolidated Balance Sheets.~~

~~(4)~~

~~Included in long-term debt in the Companies’ Consolidated Balance Sheets.~~

In addition to the amounts disclosed above, Dominion Energy’s Consolidated Balance Sheet at September 30, 2019 includes property, plant and equipment and accumulated depreciation of $2.8 billion and $341 million, respectively, related to facilities subject to power purchase agreements under which Dominion Energy is the lessor.

~~For the three and nine months ended September 30, 2019, total lease cost associated with the Companies’ lessee leasing arrangements consisted of the following:~~

Three Months Ended
September 30, 2019

Nine Months Ended
September 30, 2019

(millions)

Dominion Energy

Finance lease cost:

Amortization

$
7

$
14

Interest

1

3

Operating lease cost

20

64

Short-term lease cost

7

20

Variable lease cost

1

4

Total lease cost

$
36

$
105

Virginia Power

Operating lease cost

$
10

$
31

Short-term lease cost

3

7

Variable lease cost

1

2

Total lease cost

$
14

$
40

Dominion Energy Gas

Operating lease cost

$
3

$
10

Short-term lease cost

2

5

Total lease cost

$
5

$
15

~~For the nine months ended September 30, 2019, cash paid for amounts included in the measurement of lease liabilities consisted of the following amounts, included in the Companies’~~ Consolidated Statements of ~~Cash Flows:~~

Nine Months Ended
September 30, 2019

(millions)

Dominion Energy

Operating cash flows for finance leases

$
3

Operating cash flows for operating leases

89

Financing cash flows for finance leases

12

Virginia Power

Operating cash flows for operating leases

40

Dominion Energy Gas

Operating cash flows for operating leases

15

~~In addition to the amounts disclosed above, Dominion Energy’s Consolidated Statement of~~ Income include $53 million and $85 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019 includes $64~~2020, respectively, and $53 million and ~~$146~~$82 million for the three and six months ended June 30, 2019, respectively, of rental revenue included in operating ~~revenue and $23~~revenue. Dominion Energy’s Consolidated Statements of Income include $27 million and ~~$70~~$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.

~~At September 30, 2019, the weighted average remaining lease term and weighted discount rate for the Companies’ finance and operating leases were as follows:~~

		~~September 30, 2019~~
~~Dominion Energy~~
~~Weighted average remaining lease term - finance leases~~		~~6 years~~
~~Weighted average remaining lease term - operating leases~~		~~21 years~~
~~Weighted average discount rate - finance leases~~		~~4.36%~~
~~Weighted average discount rate - operating leases~~		~~4.58%~~
~~Virginia Power~~
~~Weighted average remaining lease term - finance leases~~		~~6 years~~
~~Weighted average remaining lease term - operating leases~~		~~17 years~~
~~Weighted average discount rate - finance leases~~		~~4.65%~~
~~Weighted average discount rate - operating leases~~		~~4.51%~~
~~Dominion Energy Gas~~
~~Weighted average remaining lease term - finance leases~~		~~6 years~~
~~Weighted average remaining lease term - operating leases~~		~~9 years~~
~~Weighted average discount rate - finance leases~~		~~4.55%~~
~~Weighted average discount rate - operating leases~~		~~4.43%~~

~~The Companies’ lease liabilities have the following scheduled maturities:~~

Maturity of Lease Liabilities

Dominion Energy

Virginia Power

Dominion Energy Gas

(millions)

Operating

Finance

Operating

Finance

Operating

Finance

2019

$
18

$
10

$
8

$
1

$
5

$
1

2020

68

39

33

3

13

2

2021

61

33

29

3

11

2

2022

50

31

23

3

9

2

2023

40

28

18

2

6

2

After 2023

538

49

160

4

25

3

Total undiscounted lease payments

775

190

271

16

69

12

Present value adjustment

(323
)

(28
)

(89
)

(2
)

(13
)

(2
)
Present value of lease liabilities

$
452

$
162

$
182

$
14

$
56

$
10

Corporate Office Leasing Arrangement

In ~~July 2016,~~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 ~~provided~~is providing equity and has obtained financing commitments from debt investors, totaling ~~$365~~$465 million, ~~which funded total~~to fund 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 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 ~~project became~~lease term will commence once construction is substantially complete ~~in August 2019 at which point~~and the facility ~~was available for Dominion Energy’s use~~is able to be occupied and ~~the five-year lease term commenced.~~

~~Upon commencement, the lease for the facility was classified as a finance lease.~~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 ~~87%~~83% of project costs, for the difference between the project costs and sale proceeds. ~~No end-of-term options were deemed reasonably certain of exercise at commencement date. At commencement,~~ Dominion Energy ~~recorded~~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 ~~offsetting~~a corresponding finance lease ~~obligation of $67 million, representing the present value of consideration over the five-year term~~liability at the ~~rate implicit in~~commencement of the ~~lease.~~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.

Note ~~16.~~15. Variable Interest Entities

There have been no significant changes regarding the entities the Companies consider VIEs as described in Note 1516 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

Dominion Energy

At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy’s securities due within one year ~~includes $31~~included $32 million and $31 million, respectively, and long-term debt ~~includes $290~~included $258 million and ~~$299~~$267 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 ~~during~~for the ~~second quarter of~~three and six months ended June 30, 2019. Virginia Power paid $13 million for electric capacity and $4$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 ~~September~~June 30, ~~2018. Virginia Power paid $13~~2020, $5 million and ~~$38~~$11 million for ~~electric capacity and $1~~the three months ended June 30, 2019, $7 million and $14 million for ~~electric energy to~~ the ~~non-utility generator in the nine~~six months ended ~~September~~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 ~~2018,~~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 ~~$83~~$86 million and ~~$31~~$27 million for the three months ended ~~September~~June 30, ~~2019, $79~~2020, respectively, and $129 million and ~~$31~~$39 million for the three months ended ~~September~~June 30, ~~2018, $301~~2019, $179 million and ~~$116~~$58 million for the ~~nine~~six months ended ~~September~~June, 30, ~~2019~~2020 and ~~$251~~$218 million and ~~$94~~$67 million for the ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, respectively. Virginia ~~Power~~Power’s Consolidated Balance Sheets include amounts due to DES of $92 million and $102 million at June 30, 2020 and December 31, 2019, respectively, recorded in payables to affiliates. Dominion Energy Gas’ Consolidated Balance Sheets ~~included~~include amounts due to DES of ~~$50~~$38 million and ~~$19~~$27 million ~~respectively,~~ at ~~September~~June 30, ~~2019,~~2020 and ~~$107 million and $46 million, respectively, at~~ December 31, ~~2018,~~2019, respectively, recorded in payables to affiliates.

Note ~~17.~~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

At ~~September~~June 30, ~~2019,~~2020, 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

2,394

3,525

6,000

210

103

5,687

(1)	This credit facility matures in March 2023 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 ~~with a~~which had an original stated maturity date in of June 2020 ~~which allows~~ 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 ~~September~~June 30, ~~2019,~~2020, Dominion Energy had $21 million in letters of credit outstanding under this agreement.

In March ~~2019, DESC’s existing $700~~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 was terminated~~facility.

DESC and ~~DESC was added~~Questar Gas’ short-term financings are supported through access as ~~a borrower~~co-borrowers to the joint revolving credit facility discussed above with Dominion Energy, Virginia Power and Dominion Energy ~~Gas~~Gas. At June 30, 2020, the sub-limits for DESC and Questar ~~Gas. At September 30, 2019,~~Gas were $500 million and $250 million, respectively.

In January 2020, DESC and GENCO applied to FERC for a two-year short-term borrowing authorization. In March 2020, FERC granted DESC authority through March 2021 to issue short-term indebtedness (pursuant to Section 204 of the ~~sub-limit for DESC was $500 million.~~

~~South Carolina Fuel Company, Inc.’s existing credit facility was terminated~~Federal Power Act) in ~~February 2019. SCANA and PSNC’s existing credit facilities were terminated~~amounts not to exceed $2.2 billion outstanding with maturity dates of one year or less. In addition, in March ~~2019. Liquidity needs for these entities may be satisfied~~2020, FERC granted GENCO authority through March 2021 to issue short-term ~~intercompany borrowings from Dominion Energy.~~indebtedness not to exceed $200 million outstanding with maturity dates of one year or less.

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 ~~September~~June 30, ~~2019,~~2020, 0 amounts were outstanding under either of these facilities.

In ~~February 2019,~~March 2020, Dominion Energy ~~Midstream terminated its~~borrowed $500 million ~~revolving credit facility subsequent to repaying the outstanding balance of $73 million, plus accrued interest.~~

~~In September 2019, Dominion Energy Questar Corporation borrowed $3.0 billion~~ under a 364-Day Term Loan Credit Agreement that bears interest at a variable rate. The proceeds ~~from the borrowing~~ were used to ~~repay~~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 ~~principal of Cove Point’s $3.0 billion term loan due in 2021.~~agreement is consistent with such allowed ratio under Dominion Energy’s joint revolving credit facility.

In April 2020, Dominion Energy ~~has provided~~borrowed $625 million under a ~~guarantee to support Dominion Energy Questar Corporation’s obligation under the~~ 364-Day Term Loan ~~Agreement.~~ Credit Agreement that bore interest at a variable rate. The proceeds were used to provide for general working capital and other general corporate purposes. In June 2020, Dominion Energy repaid the outstanding balance in full.

In November 2017, Dominion Energy filed a SEC shelf registration statement 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. At June 30, 2020 and December 31, 2019, Dominion Energy’s Consolidated Balance Sheets include $176 million and $75 million, respectively, 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 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 ~~September~~June 30, ~~2019,~~2020, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint 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

685

6,000

—

(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 the facility limit but can be changed at the option of the borrowers under the credit facility multiple times per year. At ~~September~~June 30, ~~2019,~~2020, the sub-limit for Virginia Power was $1.5 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 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 ~~September~~June 30, ~~2019,~~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

Facility

Limit⁽¹⁾

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

(millions)

Joint revolving credit facility⁽¹⁾

1,500

280

—

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 ~~September~~June 30, ~~2019,~~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 ~~2019,~~2020, Dominion Energy ~~Midstream repaid its $300 million variable rate term loan agreement due in December 2019 at~~redeemed the remaining principal outstanding ~~plus accrued interest.~~

~~In February~~of $111 million and ~~March 2019, DESC purchased certain~~$286 million of its ~~first mortgage bonds having an aggregate purchase price~~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 ~~$1.2 billion pursuant~~which was terminated in February 2020. Expenses related to ~~tender offers. Also in March 2019, SCANA purchased certain~~the early redemption of ~~its medium term notes having an aggregate purchase price of $300~~the hybrids were $10 million ~~pursuant to a tender offer. Both DESC tender offers~~reflected within interest and ~~the SCANA tender offer expired~~related charges in the ~~first quarter~~Consolidated Statements of ~~2019.~~Income for the six months ended June 30, 2020.

In March ~~2019,~~2020, SCANA redeemed its floating rate senior notes at the remaining principal balance of $66 million plus accrued interest. The notes would have otherwise matured in June 2034. Expenses related to the early redemption of the senior notes were $7 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 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 the early redemption of the medium-term notes were $14 million reflected within interest and related charges in the Consolidated Statements of Income for the six months ended June 30, 2020.

In March 2020, Dominion Energy issued $400 million of ~~4.60%~~3.30% senior notes and $350 million of 3.60% senior notes that mature in ~~2049.~~2025 and 2027, respectively.

In March ~~2019, Dominion Energy~~2020, PSNC issued, ~~an additional~~through private placement, $200 million of ~~its 4.25%~~4.05% senior notes that mature in ~~2028.~~2030.

In ~~May 2019, Virginia Power redeemed its $40 million 5.0% Economic Development Authority~~April 2020, Dominion Energy issued $1.5 billion of ~~the County of Chesterfield Pollution Control Refunding Revenue Bonds, Series 2009A, due~~3.375% senior notes that mature in ~~2023 at the principal outstanding plus accrued interest.~~2030.

In ~~May 2019, GENCO redeemed~~April 2020, Dominion Energy purchased and canceled $7 million of its ~~5.49% senior secured~~2.579% junior subordinated notes ~~due~~that mature in ~~2024 at~~July 2020. In June 2020, Dominion Energy prepaid the remaining ~~principal outstanding~~balance of ~~$33 million plus accrued interest.~~ $993 million.

In June ~~2019,~~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 ~~first mortgage lien on an electric generating facility that previously secured these~~proceeds from this offering to repay intercompany promissory notes ~~was released.~~with Dominion Energy Gas and a portion of its intercompany revolving credit agreement balance with Dominion Energy.

In ~~May 2019,~~June 2020, Virginia Power remarketed 41 series of tax-exempt bonds, with an aggregate outstanding principal of ~~$198~~$105 million to new investors. ~~NaN of the~~The bonds will bear interest at a coupon rate of ~~1.8%~~1.20% until ~~April 2022, after which it will bear interest at a market rate to be determined at that time. NaN of the bonds will bear interest at a coupon rate of 1.9% until June 2023,~~May 2024, after which they will bear interest at a market rate to be determined at that time.

In June 2019, Dominion Energy purchased and cancelled $12 million and $13 million of its June 2006 hybrids and September 2006 hybrids, respectively. All purchases were conducted in compliance with the applicable replacement capital covenant.

~~In July 2019, Virginia Power issued $500 million of 2.875% senior notes that mature in 2029.~~Derivative Restructuring

~~In August 2019, Dominion Energy issued $1.0 billion of 2.45% senior notes that mature in 2023 through a private placement.~~

~~In September 2019, DESC purchased certain of its first mortgage bonds with an outstanding principal balance of $552 million pursuant to a tender offer that expired in the third quarter of 2019.~~

In October 2019, Dominion Energy Terminal Company remarketed its $27 million Peninsula Ports Authority of Virginia Coal Terminal Revenue Refunding Bonds, Series 2003 due in 2033 resulting in a reset of the interest rate from 1.55% to 1.70% until 2022.

~~In October 2019, Dominion Energy Gas provided notice to holders to redeem its $450 million 2014 Series A 2.50% senior notes in full in November 2019 that would have otherwise matured in December 2019.~~

~~Remarketable Subordinated Notes~~

In June ~~2019,~~2020, Dominion Energy successfully remarketed its $700 million 2016 Series A-1 2.0% RSNs due 2021 and $700 million 2016 Series A-2 2.0% RSNs due 2024 pursuant to the terms of the 2016 Equity Units. In connection with the remarketing, the interest rates on the Series A-1 and Series A-2 notes were reset to 2.715% and 3.071%, respectively, payable on a semi-annual basis, and Dominion Energy ceased to have the ability to redeem the notes at its option or defer interest payments. At September 30, 2019, the securities are included in junior subordinated notes in Dominion Energy's Consolidated Balance Sheets. Dominion Energy did not receive any proceeds from the remarketing. Remarketing proceeds belonged to the investors holding the related 2016 Equity Units and were used to purchaseamended a portfolio of ~~treasury securities. Upon maturity~~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 ~~portfolio, the proceeds were applied on behalf of investors on the settlement date~~initial fair value measurement of the ~~related stock purchase contracts to pay the purchase price to Dominion Energy for the issuance~~new contract with an imputed interest rate of ~~18.5 million shares~~1.19%, in its Consolidated Balance Sheets with an embedded interest rate derivative that had a fair value of ~~its common stock in August 2019.~~ zero at inception.

Noncontrolling Interest in Dominion Energy Midstream

In June 2018, Dominion Energy, as general partner, exercised an incentive distribution right reset as defined in Dominion Energy Midstream’s partnership agreement and received 26.7 million common units representing limited partner interests in Dominion Energy Midstream. As a result of the increase in its ownership interest in Dominion Energy Midstream, Dominion Energy recorded a decrease in noncontrolling interest, and a corresponding increase in shareholders’ equity, of $375 million reflecting the change in the carrying value of the interest in the net assets of Dominion Energy Midstream held by others.

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 and to repay short-term debt, including commercial paper.

Each 2019 Series A Corporate Unit consists of a stock purchase contract 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. Stock purchase contract payments are recorded against this liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense. 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

Cumulative

Dividend Rate

Stock Purchase

Contract

Annual Rate

Stock Purchase

Contract

Liability⁽²⁾

Stock Purchase

Contract

Settlement 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

1,582

1,610

1.75

5.5

250

6/1/2022

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 ~~$17~~$41 million were made ~~in September 2019.~~during the six months ended June 30, 2020. The stock purchase contract liability was ~~$233~~$171 million and $212 million at ~~September~~June 30, ~~2019.~~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 Note 3 to the Consolidated Financial Statements for information on the issuance of Dominion Energy common stock in January 2019 in connection with the SCANA Combination. Also in January 2019, Dominion Energy acquired all outstanding partnership interests 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 ~~2019,~~2020, Dominion Energy ~~issued 18.5 million shares to settle~~began purchasing its common stock on the open market for these direct stock purchase ~~contracts entered into as part of the 2016 Equity Units and received proceeds of $1.4 billion.~~plans.

At-the-Market Program

In June 2017, Dominion Energy ~~has~~filed an SEC shelf registration statement for the sale of debt and equity securities including the ability to sell common stock through an at-the-market program ~~pursuant to which it may offer common stock~~ as discussed in Note 1920 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019. In the first quarter of 2019, Dominion Energy issued 2.1 million shares and received cash proceeds of $154 million, net of fees and commissions paid of $2 million. Following these issuances, Dominion Energy has the ability to issue $645 million of securities under its existing at-the-market program.

~~Forward Sales Agreements~~

~~Dominion Energy entered in~~ March 2018, and closed in April 2018, separate forward sale agreements with Goldman Sachs & Co. LLC and Credit Suisse Capital LLC, as forward purchasers, and an underwriting agreement with Credit Suisse Securities (USA) LLC and Goldman Sachs & Co. LLC, as representatives of the several underwriters named therein, relating to an aggregate of 20 million shares of Dominion Energy common stock. The underwriting agreement granted the underwriters a 30-day option to purchase up to an additional 3 million shares of Dominion Energy common stock, which the underwriters exercised with respect to approximately 2.1 million shares in April 2018.2020, Dominion Energy entered into four separate ~~forward sale~~sales agency agreements ~~with~~to effect sales under a new at-the-market program and pursuant to which it had the ~~forward purchasers with respect~~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.

Repurchase of Common Stock

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.

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 described in Note 21, to the ~~additional shares. In~~Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 2018, Dominion Energy received proceeds of $1.4 billion (after deducting underwriting discounts, but before deducting expenses, and subject to forward price adjustments under the forward sale agreements) upon the physical settlement of 22.1 million shares.31, 2019.

Note ~~18.~~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 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 ~~toxic~~hazardous air pollutant emissions from ~~power plants. However,~~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 ~~other requirements of the MATS rule would remain in place as the EPA is~~oil-fired electric generating units will not proposing to remove coal and oil fired power plants from the list of sources that are regulated under MATS. Although litigation of the MATS rule and the outcome of the EPA’s rulemaking are still pending, the regulation remains in effect and change. Dominion Energy and Virginia Power are complying with the applicable requirements of the rule and do not expect any ~~adverse~~ impacts to their ~~operations at this time.~~operations.

Ozone Standards

The EPA published final non-attainment designations for the October 2015 ozone standard in June 2018. States have until August 2021 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, ~~which repeals and replaces~~as a replacement for the Clean Power Plan. The ~~ACE Rule became effective in September 2019. The final~~ ACE Rule applies to existing coal-fired ~~steam electric generating units greater than or equal to 25 MW.~~power plants. The final rule includes unit-specific performance standards based on the degree of emission reduction levels achievable from unit efficiency improvements to be determined by the permitting agency. The ACE Rule requires states to develop plans by July 2022, to implement these performance ~~standards, which~~standards. These state plans must be approved by the EPA by January 2024. While the impacts of this rule could be material to Dominion Energy and Virginia Power’s 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.

~~GHG Regulation~~

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 a significant emissions rate at 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 ~~addition,~~December 2018, the EPA ~~continues to evaluate its policy regarding~~proposed revised Standards of Performance for Greenhouse Gas Emissions from New, Modified, and Reconstructed Stationary Sources. The proposed rule would amend the ~~consideration~~previous determination that the best system of CO₂ ~~emissions from biomass projects when determining whether a stationary~~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 ~~meets~~category is the ~~PSD~~most efficient demonstrated steam cycle (e.g., supercritical steam conditions for large units and ~~Title V applicability thresholds, including those~~subcritical steam conditions for small units) in combination with the application of BACT. It is unclear how the final policy will affect Virginia Power’s Altavista, Hopewell and Southampton power stations which were converted from coal to biomass under the prior biomass deferral policy; however, the expenditures to comply with any new requirements could be material to Dominion Energy and Virginia Power’s results of operations, financial condition and/or cash flows.best operating practices.

State Regulations

In May 2019, VDEQ issued a final rule establishing a state carbon regulation program with a 28.0 million ton initial state-wide carbon cap in 2020. The cap iswas to be reduced by approximately 3 percent per year through 2030, resulting in an ultimate cap of 19.6 million tons. The final rule ~~includes~~included a provision for VDEQ to delay implementation of the rule ~~and possible adjustments to the baseline cap~~ pending authorization from the General Assembly and Governor of Virginia. ~~Once~~In April 2020, Virginia legislation was enacted authorizing VDEQ ~~is authorized~~ to ~~begin implementation of~~implement the final rule. In June 2020, the VDEQ signed the CO₂ Budget Trading Program rule outlining the ~~impacts of this program could be material to Dominion Energy and Virginia Power’s results of operations, financial condition and/or cash flows; however, the existing~~requirements for Virginia’s participation in RGGI starting in 2021. The regulatory framework in Virginia provides rate recovery mechanisms that ~~could~~are expected to substantially mitigate any such impact.

The legislation discussed above is considered related legislation to the VCEA as discussed in Note 13. The VCEA institutes a mandatory renewable portfolio standard, enhances renewable generation and energy storage development, requires the retirement 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.

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 13 and 7 facilities, respectively, that ~~may be~~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 hydroelectric facilities, including one Virginia Power facility. Dominion Energy anticipates that it may have to install impingement control technologies at certain of these stations that have once-through cooling systems. Dominion Energy and Virginia Power 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 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 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 December 2023. ~~The EPA is proposing to complete new rulemaking for these waste streams.~~ While the impacts of this rule could be material to Dominion Energy and Virginia Power’s 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, ~~provides~~and similar state laws, may impose joint, several and strict liability for ~~immediate response and removal actions coordinated~~cleanup on potentially responsible parties who owned, operated or arranged for disposal at facilities affected by ~~the EPA in the event~~a release of ~~threatened~~hazardous substances. In addition, many states have created programs to incentivize voluntary remediation of sites where historical releases of hazardous substances ~~into the environment~~are identified and ~~authorizes the U.S. government either to clean up sites at which hazardous substances have created actual~~property owners or potential environmental hazards or to order persons responsible for the situation to do so. Under the CERCLA, as amended, generators and transporters of hazardous substances, as well as past and present owners and operators of contaminated sites, can be jointly, severally and strictly liable for the cost of cleanup. These potentially responsible parties ~~can be ordered~~decide to perform a cleanup, be sued for costs associated with an EPA-directed cleanup, voluntarily settle with the U.S. government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.initiate cleanups.

From time to time, Dominion Energy, Virginia Power or Dominion Energy Gas may be identified as a potentially responsible party toin connection with the alleged release of hazardous substances or wastes at a ~~Superfund~~ site. ~~The EPA (or a state) can either allow such a party to conduct~~Under applicable federal and ~~pay for a remedial investigation, feasibility study and remedial action or conduct~~state laws, the remedial investigation and action itself and then seek reimbursement from the potentially responsible parties. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion Energy, Virginia Power or Dominion Energy Gas mayCompanies 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 ~~of remedial investigation~~incurred at such sites. The Companies also may identify, evaluate and ~~actions~~remediate other potentially impacted sites under voluntary state programs. Remediation costs may be subject to reimbursement under the ~~Superfund law~~Companies’ insurance policies, rate recovery mechanisms, or ~~other laws or regulations regarding~~both. Except as described below, the ~~remediation of waste. 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 22 former manufactured gas plant sites, including certain sites associated with Virginia Power. At 11 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 ~~of which pertain to~~sites, including 1 at Virginia Power, and 12expects to conduct remediation activities primarily by the end of ~~which pertain to~~2021. At both June 30, 2020 and December 31, 2019, Dominion Energy ~~Gas. Studies conducted~~and Virginia Power have $34 million and $16 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 ~~other utilities at their former manufactured gas plant~~approximately $11 million if approved by federal and state agencies. Dominion Energy is associated with 13 additional sites, ~~have indicated that those sites contain coal tar and other potentially harmful materials. Except as disclosed below, none of the former sites~~including 2 associated with Virginia Power, which ~~the Companies~~ are ~~associated is~~not under investigation by any state or federal environmental ~~agency. At 1~~agency nor the subject of the former sites, Dominion Energy is conducting a state-approved post closure groundwater monitoring program and an environmental land use restriction has been recorded. In addition, a Virginia Power site has been accepted into a state-based voluntaryany current or proposed plans to perform remediation program. In June 2018, Virginia Power submitted a proposed remedial action plan to remove material from this site at an estimated cost of $18 million. Pending VDEQ approval, Virginia Power expects to begin remedial work at this site in late 2019. As a result, in June 2018, Virginia Power recorded a charge of $16 million ($12 million after-tax) in other operations and maintenance expense in the Consolidated Statements of Income. The 4 sites Dominion Energy acquired in the SCANA Combination associated with DESC are in various states of investigation, remediation and monitoring under work plans approved by, or under review by, the SCDHEC or the EPA. Dominion Energy anticipates that activities at these sites will continue through 2020 at an estimated cost of $10 million. In September 2018, DESC submitted an updated remediation work plan at 1 site to SCDHEC, which if approved, would increase costs by approximately $8 million. DESC expects to recover costs arising from the remediation work at all four sites through rate recovery mechanisms.activities. Due to the uncertainty surrounding ~~the other~~such sites, ~~the Companies~~Dominion Energy and Virginia Power are unable to make an estimate of the potential financial statement impacts.

~~See below for discussion on ash pond and landfill closure costs.~~

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. ~~Dominion Energy intends to vigorously contest the lawsuits, claims and assessments which have been filed or initiated against SCANA and DESC.~~ 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 and December 31, 2019 include reserves of ~~$386~~$538 million ~~included primarily within other current liabilities~~and $696 million, respectively, and insurance

receivables of ~~$173~~$8 million and $111 million, respectively, included within other ~~receivables at September~~receivables. During the six months ended June 30, ~~2019.~~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 ~~nine~~six months ended ~~September~~June 30, 2019, Dominion Energy’s Consolidated Statements of Income include charges of ~~$38~~$100 million ($2875 million after-tax) and ~~$316~~$278 million ($~~236~~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, 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 and a stay of pre-trial proceedings in the DESC Ratepayer Case. 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, 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 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, property, plant and equipment with a net recorded value of $54 million is in the process of being transferred to the plaintiffs in coordination with the court-appointed real estate trustee to satisfy the settlement ~~agreement.~~agreement, of which $26 million had been transferred as of June 30, 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 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 which was denied.~~Carolina. In December 2018, Santee Cooper filed its answer to the plaintiffs' fourth amended complaint and filed cross claims against ~~DESC.~~ 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 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 is $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 settlement will become effective upon the expiration of a 30-day appellate period. This case is pending.

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.~~ Carolina (the Luquire Case). In August 2019, DESC, SCANA and Dominion Energy were voluntarily dismissed from the case. The claims are 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 dismissed upon the effective date of the Santee Cooper Ratepayer Case settlement. This case is pending.

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.~~Carolina (the Glibowski Case). The plaintiff alleges, 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 dismissed upon the effective date of the Santee Cooper Ratepayer Case settlement. This case is pending.

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.~~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, 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 ~~October~~December 2019, the parties ~~reached~~executed a settlement ~~in principle~~agreement pursuant to which SCANA will pay $192.5 million, up to $32.5 million of which can 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. 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. 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 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. 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. ~~The~~In January 2019, the defendants ~~have~~ filed a motion to dismiss the consolidated action. In February 2019, one action was voluntarily dismissed. ~~This case is pending.~~

In November 2017, a shareholder derivative action was filed against SCANA and certain former executive officers and directors in the U.S. District Court of the District of South Carolina. Another purported shareholder derivative action was filed in the same court against nearly all of these defendants. 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. The plaintiffs allege, among other things, that the defendants violated their fiduciary duties to shareholders by disseminating false and misleading information about the NND Project, failing to maintain proper internal controls, failing to properly oversee and manage SCANA and that the individual defendants were unjustly enriched in their compensation. In June 2018,March 2020, the court denied the defendants’ ~~motions~~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 ~~and in October 2018,~~ the ~~court denied SCANA’s motion to stay all proceedings pending investigation by a Special Litigation Committee,~~appeal with ~~leave to refile after~~ the ~~SCANA Merger Approval Order was issued. The plaintiffs have agreed to a stay~~South Carolina Court of ~~this action on the condition that defendants file a motion for judgment on the pleadings,~~Appeals, which was ~~filed~~granted in ~~January 2019.~~ ~~In September 2019, the court granted the defendants’ motion for judgment and the complaint was dismissed.~~July 2020. This case is pending.

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. ~~The case is pending in the U.S. District Court for the District of South Carolina.~~

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. ~~The case is pending in the U.S. District Court for the District of South Carolina.~~

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. 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.~~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. In May 2020, SCANA filed a motion to intervene. This case is pending.

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. The ~~plaintiffs allege,~~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.

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 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 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.

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. DESC has protested the proposed assessment, which remains pending.

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 of 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 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 deemed satisfied by the settlements in the SCANA Securities Class Action and the DESC Ratepayer Case. The proposed settlement is contingent on the review and approval of final documentation by SCANA, DESC and the Staff of the SEC’s Division of Enforcement and is subject to approval by the SEC and the U.S. District Court for the District 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.

In addition, the South Carolina Law Enforcement Division is conducting a criminal investigation into the handling of the NND Project by SCANA and DESC. ~~These matters are pending. SCANA and DESC are~~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 and Cameco Corporation 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.

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. ~~DESC and Santee Cooper remain responsible for any claims that may be made by Westinghouse and WECTEC against them relating to the contract.~~

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~~$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.~~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 ~~are~~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 ~~does not believe that the~~and Santee Cooper entered into a confidential settlement agreement with W Wind Down Co LLC resolving claims ~~asserted related~~relating to the interim assessment agreement period will exceed the amounts previously funded, whether relating to claims already paid or those remaining to be paid. DESC intends to oppose any previously unasserted claim that is asserted against it, whether directly or indirectly by a claim through 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.

~~Ash Pond and Landfill Closure Costs~~

In April 2015, the EPA enacted a final rule regulating CCR landfills, existing ash ponds that still receive and manage CCRs, and inactive ash ponds that do not receive, but still store, CCRs. Dominion Energy currently operates inactive ash ponds, existing ash ponds and CCR landfills subject to the final rule at 11 different facilities, 8 of which are at Virginia Power. This rule created a legal obligation for Dominion Energy and Virginia Power to retrofit or close all of its inactive and existing ash ponds over a certain period of time, as well as perform required monitoring, corrective action, and post-closure care activities as necessary.

In December 2016, legislation was enacted that creates a framework for EPA- approved state CCR permit programs. In August 2017, the EPA issued interim guidance outlining the framework for state CCR program approval. The EPA has enforcement authority until state programs are approved. The EPA and states with approved programs both will have authority to enforce CCR requirements under their respective rules and programs. In September 2017, the EPA agreed to reconsider portions of the CCR rule in response to 2

petitions for reconsideration. In March 2018, the EPA proposed certain changes to the CCR rule related to issues remanded as part of the pending litigation and other issues the EPA is reconsidering. Several of the proposed changes would allow states with approved CCR permit programs additional flexibilities in implementing their programs. In July 2018, the EPA promulgated the first phase of changes to the CCR rule. Until all phases of the CCR rule are promulgated, Dominion Energy and Virginia Power cannot forecast potential incremental impacts or costs related to existing coal ash sites in connection with future implementation of the 2016 CCR legislation and reconsideration of the CCR rule. In August 2018, the U.S. Court of Appeals for the D.C. Circuit issued its decision in the pending challenges of the CCR rule, vacating and remanding to the EPA three provisions of the rule. Dominion Energy and Virginia Power do not expect the scope of the U.S. Court of Appeals for the D.C. Circuit’s decision to impact their closure plans, but cannot forecast incremental impacts associated with any future changes to the CCR rule in connection with the court’s remand.

In April 2017, the Governor of Virginia signed legislation into law that placed a moratorium on the VDEQ issuing solid waste permits for closure of ash ponds at Virginia Power’s Bremo, Chesapeake, Chesterfield and Possum Point power stations until May 2018. The law also required Virginia Power to conduct an assessment of closure alternatives for the ash ponds at these 4 stations, to include an evaluation of excavation for recycling or off-site disposal, surface and groundwater conditions and safety. Virginia Power completed the assessments and provided the report on December 1, 2017. In April 2018, the Governor of Virginia signed legislation into law extending the existing permit moratorium until July 2019. The legislation also required Virginia Power to solicit and compile by November 2018, information from third parties on the suitability, cost and market demand for beneficiation or recycling of coal ash from these units. The coal ash recycling business plan was submitted to the legislature in November 2018. The extended moratorium does not apply to a permit required for an impoundment where CCRs have already been removed and placed in another impoundment on-site, are being removed from an impoundment, or are being processed in connection with a recycling or beneficial use project. In connection with this legislation, in the second quarter of 2018, Virginia Power recorded an increase to its ARO and a related environmental liability related to future ash pond and landfill closure costs of $131 million, which resulted in an $81 million ($60 million after-tax) charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $46 million increase in property, plant and equipment associated with asset retirement costs and a $4 million increase in regulatory assets.

In March 2019, the Governor of Virginia signed into law legislation which requires any CCR unit located at Virginia Power’s Bremo, Chesapeake, Chesterfield or Possum Point power stations that stop accepting CCR prior to July 2019 be closed by removing the CCR to an approved landfill or through recycling for beneficial reuse. The legislation further requires that at least 6.8 million cubic yards of CCR be beneficially reused and that costs associated with the closure of these CCR units be recoverable through a rate adjustment clause approved by the Virginia Commission with a revenue requirement that cannot exceed $225 million in any 12-month period. In connection with this legislation, Virginia Power recorded a $2.4 billion ARO related to the cost of landfills and beneficial reuse, with an offsetting increase to property, plant and equipment of $1.3 billion for the Chesterfield power station and an increase primarily to regulatory assets for the remaining portion related to the Bremo, Chesapeake and Possum Point power stations during the first quarter of 2019. In addition, Virginia Power revised its estimated cash flows for the existing ARO related to future ash pond and landfill closure costs, which resulted in a decrease of $202 million and a corresponding $113 million ($84 million after-tax) benefit in other operations and maintenance expense in the Consolidated Statement of Income in the first quarter of 2019. The actual AROs related to CCRs may vary substantially from the estimates used to record the obligation.

Nuclear Matters

In March 2011, a magnitude 9.0 earthquake and subsequent tsunami caused significant damage at the Fukushima Daiichi nuclear power station in northeast Japan. These events ~~have~~ resulted in significant nuclear safety reviews ~~required~~ by the NRC and industry groups such as the Institute of Nuclear Power Operations. Like other U.S. nuclear operators, Dominion Energy has ~~been gathering~~gathered supporting data and ~~participating~~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 of the Fukushima Daiichi accident and in October 2011 the NRC staff prioritized these recommendations into Tiers 1, 2 and ~~3, with the~~3. Tier 1 recommendations ~~consisting~~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 dependent on activities related to the higher priority Tier 1 issues. In December 2011, the NRC Commissioners approved the agency ~~staff's~~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 ~~reactors,~~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 ~~to respond~~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 ~~request~~requested each reactor licensee to reevaluate the seismic and external flooding hazards at their ~~site~~facility using present-day methods and information, conduct walkdowns of their ~~facilities~~facility to ensure protection against ~~the~~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 ~~was completed or in review~~is complete and final with ~~the~~ NRC ~~in 2018.~~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 ~~continue through 2019.~~accept the analysis in 2020. Dominion Energy and Virginia Power do not currently expect that compliance with the ~~NRC's~~NRC’s information requests will materially impact their financial position, results of operations or cash flows during the implementation period. The NRC staff ~~is evaluating~~has resolved the ~~implementation of the longer term~~ 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.

Nuclear Operations

Nuclear Insurance

During the second quarter of ~~2019,~~2020, the total liability protection per nuclear incident available to all participants in the Secondary Financial Protection Program decreased from ~~$14.1~~$13.9 billion to ~~$13.9~~$13.8 billion. This decrease does not impact Dominion Energy’s responsibility per active unit under the Price-Anderson Amendments Act of 1988.

Spent Nuclear Fuel

As discussed in ~~Notes 3 and 22~~Note 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018,~~2019, Dominion Energy and Virginia Power ~~and DESC~~ 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 ~~for the period January 1, 2014 through December 31, 2017.~~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

Dominion ~~Energy entered into a~~Energy’s guarantee agreement to support a portion of Atlantic Coast Pipeline’s obligation under a ~~$3.4 billion~~ revolving credit facility ~~with a stated maturity date of October 2021. Dominion Energy’s maximum potential loss exposure under the terms of the guarantee~~ is ~~limited to 48% of the outstanding borrowings under the revolving credit facility, an equal percentage to Dominion Energy’s ownership~~described in Atlantic Coast Pipeline. As of September 30, 2019, Atlantic Coast Pipeline has borrowed $1.7 billion against the revolving credit facility and borrowed an additional $41 million in October 2019. Dominion Energy’s Consolidated Balance Sheets include a liability of $15 million and $21 million associated with this guarantee agreement at September 30, 2019 and December 31, 2018, respectively.

Note 10. In addition, at ~~September~~June 30, ~~2019,~~2020, Dominion Energy had issued an additional $27 million of guarantees, primarily to support other equity method investees. No amounts related to the other 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 ~~September~~June 30, ~~2019,~~2020, Dominion Energy had issued the following subsidiary guarantees:

	Maximum Exposure		Maximum Exposure
(millions)
Commodity transactions⁽¹⁾	$	2,517	$	2,215
Nuclear obligations⁽²⁾		204		224
Cove Point⁽³⁾		1,900		1,900
Solar⁽⁴⁾		652		449
Other⁽⁵⁾		390		460
Total⁽⁶⁾	$	5,663	$	5,248

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

(6)

Excludes Dominion Energy's ~~guarantee~~guarantees for the new corporate office ~~property~~properties discussed in Note 2215 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019 and ~~guarantees for debt of certain subsidiaries discussed~~ in Note ~~17.~~14 in this report.

Additionally, at ~~September~~June 30, ~~2019,~~2020, Dominion Energy had purchased ~~$185~~$177 million of surety bonds, including ~~$81~~$89 million at Virginia Power and ~~$26~~$27 million at Dominion Energy Gas, and authorized the issuance of letters of credit by financial institutions of ~~$81~~$103 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 ~~19.~~18. Credit Risk

The Companies’ accounting policies for credit risk are discussed in Note 2324 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

At ~~September~~June 30, ~~2019,~~2020, Dominion Energy’s gross credit exposure related to energy marketing and price risk management activities totaled ~~$149~~$215 million. Of this amount, investment grade counterparties, including those internally rated, represented ~~91%~~95%. NaN single counterparty, whether investment grade or non-investment grade, exceeded ~~$33~~$53 million of exposure. At ~~September~~June 30, ~~2019,~~2020, Virginia Power’s exposure related to wholesale customers totaled ~~$46~~$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 ~~$32~~$3 million of exposure. ~~At September~~

For the three and six months ended June 30, ~~2019,~~2020, the Export Customers comprised approximately 36% and 34%, respectively, of Dominion Energy Gas’ exposure primarily related to wholesale customers totaled $35 million. Of this amount, investment grade counterparties, including those internally rated, represented 90%. NaN single counterparty, whether investment grade or non-investment grade, exceeded $6 milliontotal operating revenue, with Dominion Energy Gas’ largest customer representing approximately 19% and 18%, respectively, of ~~exposure.~~ 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 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 ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy would have been required to post $4$13 million and $1$10 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 no$4 million of collateral at ~~September~~June 30, ~~2019 or December 31, 2018~~2020 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with ~~cash.~~cash and had posted 0 collateral at December 31, 2019. 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 ~~immaterial~~$17 million and $10 million at ~~both September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 June 30, 2020 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 ~~Virginia Power and~~ Dominion Energy Gas were ~~immaterial~~not material as of ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018.~~2019. See Note 9 for further information about derivative instruments.

Note ~~20.~~19. Related-Party Transactions

Virginia Power and Dominion Energy Gas engage in related-party transactions primarily with other Dominion Energy subsidiaries (affiliates). Virginia ~~Power's~~Power and Dominion Energy Gas’ 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 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 ~~September~~June 30, 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 ~~$18 million, respectively. At December 31, 2018, Virginia Power’s derivative assets and liabilities with affiliates were $26 million and $10~~$53 million, respectively. See Note 9 for more information.

Virginia Power participates in certain Dominion Energy benefit plans described in Note 2122 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 ~~$750~~$838 million and ~~$632~~$782 million, respectively. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, 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 ~~$272~~$318 million and ~~$254~~$287 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 September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018		2020		2019		2020		2019
(millions)
Commodity purchases from affiliates	$	170	$	196	$	561	$	733	$	104	$	119	$	315	$	391
Services provided by affiliates⁽¹⁾		107		106		387		338		114		161		235		280
Services provided to affiliates		5		6		19		17		4		8		9		14

(1)

Includes capitalized expenditures of~~$33 million and~~ $34 million for both the three months ended ~~September~~June 30, 2020 and 2019, and ~~2018, respectively, and $100~~$68 million and ~~$109~~$67 million for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~2019, respectively.

Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were ~~$9 million and $224~~$340 million in short-term demand note borrowings from Dominion Energy as of ~~September~~June 30, ~~2019~~2020 and $107 million in short-term demand note borrowings from Dominion Energy as of December 31, ~~2018, respectively.~~2019. Virginia Power had 0 outstanding borrowings, net of repayments, under the Dominion Energy money pool for its nonregulated subsidiaries as of ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018.~~2019. Interest charges related to Virginia Power’s borrowings from Dominion Energy were immaterial for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018.~~2019.

There were 0 issuances of Virginia Power’s common stock to Dominion Energy for the three and ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018.~~2019.

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 ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018, all of~~2019, Dominion Energy ~~Gas'~~Gas did 0t have any commodity ~~derivatives were~~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, ~~2018.~~2019. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, amounts due from Dominion Energy associated with the Dominion Energy Pension Plan included in ~~noncurrent pension~~other deferred charges and other ~~postretirement benefit~~ assets in the Consolidated Balance Sheets were ~~$793~~$334 million and ~~$772~~$326 million, respectively. At ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy Gas’ amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan included in ~~noncurrent pension~~other deferred charges and other ~~postretirement benefit~~ assets in the Consolidated Balance Sheets were ~~$16~~$20 million and ~~$14~~$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.~~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 isare 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 September 30,				Nine Months Ended September 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018		2020		2019		2020		2019
(millions)
Sales of natural gas and transportation and storage services to affiliates	$	16	$	17	$	51	$	51
Purchases of natural gas from affiliates		4		1		10		2
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⁾		32		32		117		98		37		59		80		104
Services provided to related parties⁽²⁾		26		53		88		166		29		45		61		90

(1)

Includes capitalized expenditures of ~~$10~~$4 million and $5 million for ~~both~~ the three months ended ~~September~~June 30, 2020 and 2019, respectively, and ~~2018 and $22~~$7 million and ~~$27~~$11 million for the ~~nine~~six months ended ~~September~~June 30, ~~2019~~2020 and ~~2018,~~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:

	September 30, 2019		December 31, 2018		June 30, 2020		December 31, 2019
(millions)
Other receivables⁽¹⁾	$	9	$	13	$	7	$	7
Customer receivables from related parties		—		1
Imbalances receivable from affiliates		—		1		3		8
Imbalances payable to affiliates⁽²⁾		1		13		2		1
Affiliated notes receivable⁽³⁾		13		16
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.

~~(3)~~

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.

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

Dominion Energy Gas’ borrowings under the intercompany revolving credit agreement with Dominion Energy ~~were $160~~totaled $314 million and ~~$218~~$251 million as of ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~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 ~~September~~June 30, 2020, respectively, and were less than $1 million and $1 million for the three and six months ended June 30, 2019, ~~and 2018 and $2~~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 ~~nine~~three and six months ended ~~September~~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 ~~2018,~~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 ~~21.~~20. Employee Benefit Plans

Dominion Energy

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’s provision for net periodic benefit cost (credit) ~~were~~are as follows:

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

Pension Benefits

Other Postretirement Benefits

2019

2018

2019

2018

(millions)

Three Months Ended September 30,

Service cost

$
41

$
39

$
7

$
7

Interest cost

97

85

17

14

Expected return on plan assets

(177
)

(165
)

(37
)

(36
)
Amortization of prior service credit

—

—

(13
)

(13
)
Amortization of net actuarial loss

42

48

2

3

Settlements⁽¹⁾

2

—

—

—

Net periodic benefit cost (credit)

$
5

$
7

$
(24
)

$
(25
)
Nine Months Ended September 30,

Service cost

$
121

$
118

$
20

$
20

Interest cost

296

253

51

42

Expected return on plan assets

(530
)

(498
)

(105
)

(107
)
Amortization of prior service cost (credit)

1

1

(39
)

(39
)
Amortization of net actuarial loss

124

145

9

8

Settlements and curtailment⁽¹⁾

75

—

42

—

Net periodic benefit cost (credit)

$
87

$
19

$
(22
)

$
(76
)

~~(1)~~

~~Primarily related~~

(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. ~~The voluntary retirement program will not compromise safety or the Companies’ ability to comply with applicable laws and regulations.~~ 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 ~~$63~~$74 million ($4858 million after-tax) included within other operations and maintenance expense ($5939 million), other taxes ($32 million) ~~and~~, other income ($1 million) and discontinued operations ($32 million) in ~~the~~their respective Consolidated Statements of Income.

In See Note 22 to the second quarter of 2019, Dominion Energy and Dominion Energy Gas remeasured their pension and other postretirement benefit plans as a result of the voluntary retirement program. The remeasurement resulted in an increaseConsolidated Financial Statements in the pension benefit obligation of $484 million and $32 million and an increase in the fair value of the pension plan assets of $671 million and $146 million for Dominion Energy and Dominion Energy Gas, respectively. In addition, the remeasurement resulted in an increase in the accumulated postretirement benefit obligation of $101 million and $8 million and an increase in the fair value of the other postretirement benefit plan assets of $156 million and $29 million for Dominion Energy and Dominion Energy Gas, respectively. The impact of the remeasurementCompanies’ Annual Report on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date. The remeasurement is expected to increase the net periodic benefit credit for 2019 by approximately $6 million and $4 million for Dominion Energy and Dominion Energy Gas, respectively, excluding the impacts of curtailments. The discount rate usedForm 10-K for the remeasurement was 4.07% - 4.10% for the Dominion Energy pension plans, 4.10% for Dominion Energy Gas pension plans, 4.05% - 4.08% for the Dominion Energy other postretirement benefit plans, and 4.05% for the Dominion Energy Gas other postretirement benefit plans. All other assumptions used for the remeasurement were consistent with the measurement as ofyear ended December 31, ~~2018.~~

~~In the third quarter of~~ 2019 Dominion Energy remeasured a pension plan as a result of a settlement from the voluntary retirement program at SCANA. The settlement and related remeasurement resulted in an increase in the pension benefit obligation of $37 million and an increase in the fair value of the pension plan assets of $51 million for Dominion Energy. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date. The remeasurement is expected to increase the net periodic benefit credit for 2019 by $7 million. The discount rate used for the remeasurement was 3.57%. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2018. more information.

Employer Contributions

During the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, Dominion Energy made 0 contributions to its qualified defined benefit pension plans or other postretirement benefit plans. Dominion Energy ~~made a contribution of $21 million~~does 0t expect to make contributions to its defined benefit pension plans ~~in October 2019~~ and expects to ~~make a~~contribute $12 million ~~contribution~~ to ~~its~~ other postretirement benefit plans through VEBAs, respectively, during the remainder of ~~2019.~~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 to make any further contributions to other postretirement plans in 2020.

Dominion Energy Gas

Dominion Energy Gas participates in certain Dominion Energy benefit plans as described in Note 2122 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019. See Note 2019 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 ~~were~~are as follows:

	Pension Benefits						Other Postretirement Benefits						Pension Benefits						Other Postretirement Benefits
	2019			2018			2019			2018			2020			2019			2020			2019
(millions)
Three Months Ended September 30,
Service cost	$	4		$	4		$	—		$	1
Interest cost		7			7			3			3
Expected return on plan assets		(38	)		(36	)		(6	)		(7	)
Amortization of prior service credit		—			—			(1	)		(1	)
Amortization of net actuarial loss		5			4			—			—
Net periodic benefit credit	$	(22	)	$	(21	)	$	(4	)	$	(4	)
Nine Months Ended September 30,
Three Months Ended June 30,
Service cost	$	12		$	13		$	2		$	3		$	2		$	4		$	—		$	1
Interest cost		23			21			8			8			2			8			1			2
Expected return on plan assets		(116	)		(111	)		(20	)		(21	)		(14	)		(39	)		(5	)		(7	)
Amortization of prior service credit		—			—			(3	)		(3	)		—			—			(1	)		(1	)
Amortization of net actuarial loss		15			14			2			2			2			5			1			1
Curtailment⁽¹⁾		1			—			1			—			—			1			—			1
Net periodic benefit credit	$	(65	)	$	(63	)	$	(10	)	$	(11	)	$	(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)~~

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

~~Related to a voluntary retirement program.~~

Employer Contributions

During the ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, Dominion Energy Gas made 0 contributions to its qualified defined benefit pension ~~plans~~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 ~~2019.~~2020.

Note ~~22.~~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
~~Power Delivery~~Dominion Energy Virginia	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
~~Power Generation~~	Regulated electric generation fleet⁽¹⁾	X	X
Gas Transmission & Storage	~~Merchant electric generation fleet~~	X
~~Gas Infrastructure~~	~~Gas~~Regulated gas transmission and storage	X		X
	~~Gas distribution and storage~~	X		X
	~~Gas gathering and processing~~⁽²⁾	X		X
	LNG terminalling and storage	X		X
	Nonregulated retail energy marketing	X
~~Southeast~~Gas Distribution	Regulated gas distribution and storage⁽³⁾	X
Dominion Energy South Carolina	Regulated electric distribution	X
	Regulated electric transmission	X
	Regulated electric generation fleet	X
	~~Gas~~Regulated gas distribution and storage	X
Contracted Generation	~~Nonregulated retail energy marketing~~Merchant electric generation fleet	X

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

(2)	Includes gathering and processing activities.

(3)	Includes 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). 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 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 for the six months ended June 30, 2019 presented herein has been recast to reflect the current segment presentation.

In the ~~nine~~six months ended ~~September~~June 30, 2020, Dominion Energy reported after-tax net expenses of $3.1 billion for specific items in the Corporate and Other segment, with $2.9 billion of net expenses attributable to its operating segments. In the six months ended June 30, 2019, Dominion Energy reported after-tax net expenses of $2.1 billion for specific items in the Corporate and Other segment, with ~~$2.0~~$1.8 billion of net expenses attributable to its operating segments. ~~In the nine months ended September 30, 2018, Dominion Energy reported after-tax~~

The net ~~expenses of $253 million~~expense for specific items ~~in the Corporate and Other segment, with $188 million of net expenses~~ attributable to ~~its~~Dominion Energy’s operating ~~segments.~~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 ($100 million after-tax) and;

•

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

The net expense for specific items attributable to Dominion Energy’s operating segments in 2019 primarily related to the impact of the following items:

•	A $1.0 billion ($~~760~~756 million after-tax) charge for refunds of amounts previously collected ~~primarily~~ from retail electric customers of DESC for the NND Project,, attributable to ~~Southeast Energy;~~Dominion Energy South Carolina;

•	$~~570~~446 million ($~~429~~339 million after-tax) of merger and integration-related costs associated with the SCANA Combination, including a ~~$444~~$425 million ($~~332~~317 million after-tax) charge related to a voluntary retirement program, attributable to:

•

~~Power Delivery~~Dominion Energy Virginia ($77145 million after-tax);

•

~~Power Generation ($110 million after-tax);~~

•

Gas ~~Infrastructure~~Transmission & Storage ($8239 million after-tax); ~~and~~

•

~~Southeast Energy~~Gas Distribution ($~~160~~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 ~~Power Generation;~~Dominion Energy Virginia;

•	$~~316~~278 million ($~~237~~209 million after-tax) of charges associated with litigation acquired in the SCANA Combination, attributable to ~~Southeast Energy;~~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 ~~Southeast Energy;~~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 ~~Power Delivery;~~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 ~~Power Generation;~~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 ~~forgo~~forego recovery, attributable to ~~Southeast Energy;~~Dominion Energy South Carolina; partially offset by

•	A ~~$364~~$336 million ($~~272~~251 million after-tax) net gain related to investments in nuclear decommissioning trust funds, attributable ~~to Power Generation;~~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 ~~Power Generation.~~

~~The net expense for specific items attributable to Dominion Energy’s operating segments in 2018 primarily related to the impact of the following items:~~

•	~~A $215 million ($160 million after-tax) charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers, attributable to:~~

•

~~Power Generation ($109 million after-tax); and~~

•

~~Power Delivery ($51 million after-tax);~~

•	~~A $156 million ($121 million after-tax) increased net investment earnings on nuclear decommissioning trust funds attributable to Power Generation;~~

•	~~A $124 million ($88 million after-tax) charge for disallowance of FERC-regulated plant, attributable to Gas Infrastructure; and~~

•

An $81 million ($60 million after-tax) charge associated primarily with the asset retirement obligations for ash ponds and landfills at certain utility generation facilities in connection with the enactment of Virginia legislation in April 2018 attributable to Power Generation.Dominion Energy Virginia.

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

	Power Delivery		Power Generation		Gas Infrastructure		Southeast Energy		Corporate and Other			Adjustments/ Eliminations			Consolidated Total		Dominion Energy Virginia			Gas Transmission & Storage		Gas Distribution		Dominion Energy South Carolina		Contracted Generation		Corporate and Other			Adjustments & Eliminations			Consolidated Total
(millions)
Three Months Ended September 30, 2019
Three Months Ended June 30, 2020
Total revenue from external customers	$	678	$	1,848	$	788	$	973	$	(18	)	$	—		$	4,269	$	1,818		$	528	$	400	$	634	$	238	$	(32	)	$	(1	)	$	3,585
Intersegment revenue		5		6		28		—		164			(203	)		—		(4	)		49		2		1		5		262			(315	)		—
Total operating revenue		683		1,854		816		973		146			(203	)		4,269		1,814			577		402		635		243		230			(316	)		3,585
Net income (loss) attributable to Dominion Energy		185		490		232		147		(79	)		—			975		437			184		87		75		21		(1,973	)		—			(1,169	)
Three Months Ended September 30, 2018
Total revenue from external customers	$	596	$	2,021	$	836			$	—		$	(2	)	$	3,451
Intersegment revenue		5		3		7				160			(175	)		—
Total operating revenue		601		2,024		843				160			(177	)		3,451
Net income attributable to Dominion Energy		163		414		264				13			—			854
Nine Months Ended September 30, 2019
Three Months Ended June 30, 2019
Total revenue from external customers	$	1,861	$	5,191	$	3,042	$	3,070	$	(1,067	)	$	—		$	12,097	$	1,945		$	664	$	397	$	701	$	249	$	(18	)	$	32		$	3,970
Intersegment revenue		17		15		83		—		611			(726	)		—		(2	)		91		3		2		4		386			(484	)		—
Total operating revenue		1,878		5,206		3,125		3,070		(456	)		(726	)		12,097		1,943			755		400		703		253		368			(452	)		3,970
Net income (loss) attributable to Dominion Energy		496		1,048		838		361		(2,394	)		—			349		393			177		66		95		13		(690	)		—			54
Nine Months Ended September 30, 2018
Six Months Ended June 30, 2020
Total revenue from external customers	$	1,687	$	5,516	$	2,972			$	(210	)	$	40		$	10,005	$	3,756		$	1,172	$	1,287	$	1,347	$	524	$	(4	)	$	(1	)	$	8,081
Intersegment revenue		17		8		21				505			(551	)		—		(7	)		106		5		2		9		541			(656	)		—
Total operating revenue		1,704		5,524		2,993				295			(511	)		10,005		3,749			1,278		1,292		1,349		533		537			(657	)		8,081
Net income (loss) attributable to Dominion Energy		464		1,038		840				(536	)		—			1,806		866			405		312		169		80		(3,271	)		—			(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.

Virginia Power

The Corporate and Other Segment of Virginia Power primarily includes specific items attributable to its operating ~~segments~~segment that are not included in profit measures evaluated by executive management in assessing the ~~segments'~~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 ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, Virginia Power reported after-tax net expenses of ~~$673~~$654 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, Virginia Power reported after-tax expense of $652 million for specific items in the Corporate and Other segment, with ~~$653~~$607 million of net expenses attributable to its operating segments. In the nine months ended September 30, 2018, Virginia Power reported after-tax net expenses of $229 million for specific items in the Corporate and Other segment, with $226 million of net expenses attributable to its operating segments.segment.

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

•	A ~~$197~~$192 million ($~~146~~143 million after-tax) charge related to a voluntary retirement ~~program, attributable to:~~program;

•

~~Power Delivery ($74 million after-tax); and~~

•

~~Power Generation ($72 million after-tax);~~

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

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

•	A $62 million ($46 million after-tax) charge related the abandonment of a project at an electric generating ~~facility, attributable to Power Generation;~~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, attributable to Power Generation.~~

~~The net expense for specific items attributable to Virginia Power’s operating segments in 2018 primarily related to the impact of the following items:~~

•	~~A $215 million ($160 million after-tax) charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers, attributable to:~~

•

~~Power Generation ($109 million after-tax); and~~

•

~~Power Delivery ($51 million after-tax); and~~

•	An $81 million ($60 million after-tax) charge associated primarily with the asset retirement obligations for ash ponds and landfills at certain utility generation facilities in connection with the enactment of Virginia legislation in April 2018 attributable to Power Generation.2019.

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

	Power Delivery		Power Generation		Corporate and Other			Consolidated Total		Dominion Energy Virginia		Corporate and Other			Consolidated Total
(millions)
Three Months Ended September 30, 2019
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	$	677	$	1,587	$	—		$	2,264	$	1,938	$	—		$	1,938
Net income (loss)		184		444		(26	)		602		393		(293	)		100
Three Months Ended September 30, 2018
Operating revenue	$	595	$	1,637	$	—		$	2,232
Net income		163		347		10			520
Nine Months Ended September 30, 2019
Six Months Ended June 30, 2020
Operating revenue	$	1,860	$	4,336	$	(29	)	$	6,167	$	3,735	$	—		$	3,735
Net income (loss)		494		885		(657	)		722		862		(652	)		210
Nine Months Ended September 30, 2018
Six Months Ended June 30, 2019
Operating revenue	$	1,686	$	4,338	$	(215	)	$	5,809	$	3,932	$	(29	)	$	3,903
Net income (loss)		462		796		(215	)		1,043		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 ~~nine~~six months ended ~~September~~June 30, ~~2019,~~2020, Dominion Energy Gas reported after-tax net expenses of ~~$53~~$365 million for specific items in the Corporate and Other segment, all of which ~~are~~was attributable to its operating segment. In the ~~nine~~six months ended ~~September~~June 30, ~~2018,~~2019, Dominion Energy Gas reported after-tax net expenses of ~~$100~~$44 million for specific items in the Corporate and Other segment, with ~~$99~~$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 ~~$63~~$42 million ($4831 million after-tax) charge related to a voluntary retirement ~~program, attributable to Gas Infrastructure.~~program.

The net expense for specific items attributable to Dominion Energy Gas’ operating segment in 2018 primarily related to a $124 million ($88 million after-tax) charge for disallowance of FERC-regulated plant, attributable to Gas Infrastructure.

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

Gas
Infrastructure

Corporate and
Other

Consolidated
Total

(millions)

Three Months Ended September 30, 2019

Operating revenue

$
392

$
—

$
392

Net income (loss)

100

(8
)

92

Three Months Ended September 30, 2018

Operating revenue

$
423

$
—

$
423

Net income (loss)

146

(10
)

136

Nine Months Ended September 30, 2019

Operating revenue

$
1,314

$
(11
)

$
1,303

Net income (loss)

316

(61
)

255

Nine Months Ended September 30, 2018

Operating revenue

$
1,408

$
—

$
1,408

Net income (loss)

421

(104
)

317

	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

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’s~~Power and Dominion Energy Gas’ results of operations. MD&A should be read in conjunction with the Companies’ Consolidated Financial Statements. Virginia Power and Dominion Energy Gas meet the conditions to file under the reduced disclosure format, and therefore have 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 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 and regulated gas distribution, transportation and storage rates, including LNG storage, collected by Dominion Energy and Dominion Energy Gas;

•	Changes in rules for ~~regional transmission organizations~~RTOs and ~~independent system operators~~ISOs in which Dominion Energy and Virginia Power 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 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 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 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’ pipeline ~~and processing~~ systems, 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, ~~including the recently completed SCANA Combination,~~ divestitures, transfers of assets to joint ventures and retirements of assets based on asset portfolio reviews;

•	The expected timing and likelihood of completion of the proposed transaction with BHE, 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 and in benefit plan trusts by Dominion Energy and Dominion Energy Gas;

•	Fluctuations in energy-related commodity prices and the effect these could have on Dominion Energy’s ~~and Dominion Energy Gas’~~ 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;~~

•	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, ~~2018.~~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 ~~September~~June 30, ~~2019,~~2020, 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, ~~2018.~~2019. The policies disclosed included the accounting for regulated operations, AROs, income taxes, derivative contracts and financial instruments at fair value, impairment testing of goodwill, long-lived assets and equity method investments and employee benefit plans.

Dominion Energy

Results of Operations

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

	2019		2018		$ Change			2020			2019			$ Change
(millions, except EPS)
Third Quarter
Net income attributable to Dominion Energy	$	975	$	854	$	121
Second Quarter
Net income (loss) attributable to Dominion Energy								$	(1,169	)	$	54		$	(1,223	)
Diluted EPS		1.17		1.30		(0.13	)		(1.41	)		0.05			(1.46	)
Year-To-Date
Net income attributable to Dominion Energy	$	349	$	1,806	$	(1,457	)
Net loss attributable to Dominion Energy								$	(1,439	)	$	(626	)	$	(813	)
Diluted EPS		0.39		2.77		(2.38	)		(1.75	)		(0.78	)		(0.97	)

Overview

~~Third~~Second Quarter ~~2019~~2020 vs. ~~2018~~2019

Net income attributable to Dominion Energy ~~increased 14%,~~decreased $1.2 billion, primarily due to ~~operations acquired in~~charges associated with the ~~SCANA Combination, higher renewable energy investment tax credits, decreased Virginia Power electric capacity expense~~cancellation of the Atlantic Coast Pipeline Project and ~~an increase in cooling degree days in Virginia Power’s service territory. These increases were~~related portions of the Supply Header Project partially offset by ~~a decrease~~an increase in net investment earnings on nuclear decommissioning trust funds, the absence of charges related to a ~~gain on sale~~voluntary retirement program, the absence of ~~an equity method investment~~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 ~~gains related to agreements to convey shale development rights under natural gas storage fields.~~

a charge for the abandonment of a project at a Virginia Power electric generating facility.

Year-To-Date ~~2019~~2020 vs. ~~2018~~2019

Net ~~income~~loss attributable to Dominion Energy ~~decreased $1.5 billion,~~increased $813 million, primarily due to charges 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 charges associated with the planned early retirements of certain electric generation facilities in Virginia. 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 ~~a voluntary retirement program, the planned early retirement of~~and for certain ~~Virginia Power electric generation facilities and automated meter reading infrastructure,~~ 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, ~~Virginia Power’s contract termination with a non-utility generator and~~ the absence of gains related to agreements to convey shale development rights under natural gas storage fields. These decreases were partially offset by an increase in net investment earnings on nuclear decommissioning trust funds, the operations acquired in the SCANA Combination, the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019, the absence of charges ~~associated with~~for the planned early retirement of certain Virginia ~~legislation enacted in March 2018 and April 2018~~Power automated meter reading infrastructure and the absence of ~~disallowance of FERC-regulated plant.~~charges related to a voluntary retirement program.

Analysis of Consolidated Operations

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

	Third Quarter							Year-To-Date							Second Quarter								Year-To-Date
	2019		2018		$ Change			2019		2018		$ Change			2020			2019		$ Change			2020			2019		$ Change
(millions)
Operating revenue	$	4,269	$	3,451	$	818		$	12,097	$	10,005	$	2,092		$	3,585		$	3,970	$	(385	)	$	8,081		$	7,828	$	253
Electric fuel and other energy-related purchases		774		761		13			2,283		2,128		155			505			718		(213	)		1,173			1,509		(336	)
Purchased electric capacity		11		50		(39	)		74		87		(13	)		11			24		(13	)		13			63		(50	)
Purchased gas		153		5		148			1,110		409		701			74			227		(153	)		501			957		(456	)
Net revenue		3,331		2,635		696			8,630		7,381		1,249			2,995			3,001		(6	)		6,394			5,299		1,095
Other operations and maintenance		1,010		770		240			3,295		2,438		857			995			1,283		(288	)		2,038			2,285		(247	)
Depreciation, depletion and amortization		679		526		153			1,991		1,487		504			673			661		12			1,346			1,312		34
Other taxes		243		177		66			819		542		277			256			284		(28	)		540			576		(36	)
Impairment of assets and other charges		85		12		73			1,232		147		1,085			531			312		219			1,299			1,147		152
Other income		173		373		(200	)		653		658		(5	)		502			53		449			50			400		(350	)
Earnings (loss) from equity method investees																(2,281	)		39		(2,320	)		(2,228	)		80		(2,308	)
Interest and related charges		451		378		73			1,372		1,053		319			449			452		(3	)		939			921		18
Income tax expense		51		262		(211	)		208		485		(277	)
Income tax expense (benefit)																(556	)		43		(599	)		(575	)		157		(732	)
Noncontrolling interests		10		29		(19	)		17		81		(64	)		37			4		33			68			7		61

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

~~Third~~Second Quarter ~~2019~~2020 vs. ~~2018~~2019

Net revenue ~~increased 26%,~~remained substantially consistent, primarily ~~due to:~~reflecting:

•	A ~~$607~~$60 million ~~increase~~decrease in sales to electric utility retail customers from ~~operations acquired~~a decrease in cooling degree days;

•	A $44 million decrease in sales to electric utility retail customers associated with usage factors impacted by COVID-19;

•	A $20 million decrease due to unfavorable pricing at Millstone, including the ~~SCANA Combination;~~effects of the Millstone 2019 power purchase agreements; and

•	A $14 million net unrealized loss on freestanding commodity derivatives.

These decreases were substantially offset by:

•	A ~~$96~~$98 million increase from Virginia Power rate adjustment clauses;

•	The absence of a $24 million loss as a result of the contribution of SEMI to Wrangler; and

•

A ~~$40~~$16 million decrease in Virginia Power electric capacity expense related to the annual PJM capacity performance market effective June 2019 ($2721 million) ~~and a contract termination with a non-utility generator~~partially offset by the expiration of various contracts ($135 million)~~; and~~

•	~~A $31 million increase in sales to Virginia Power retail customers, primarily due to an increase in cooling degree days during the cooling season.~~

~~These increases were partially offset by:~~

•	~~A $67 million decrease from the absence of certain merchant generation facilities sold in 2018; and~~

•	~~A $26 million decrease in services performed for Atlantic Coast Pipeline.~~.

Other operations and maintenance ~~increased 31%~~decreased 22%, primarily reflecting:

•	~~A $165 million increase from operations acquired in the SCANA Combination;~~

•	The absence of ~~gains~~a charge related to ~~agreements to convey shale development rights under natural gas storage fields~~a voluntary retirement program ($65288 million);

•	A ~~$47~~$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 ~~transmission-related expenditures. These expenses~~expenditures, which are primarily recovered through state and FERC rates and do not impact net ~~income;~~income; 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 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 ~~merger and integration-related~~dismantling costs associated with ~~the SCANA Combination~~certain Virginia Power electric generation facilities ($2630 million); partially offset by

•	~~A $26~~The absence of a $135 million ~~decrease~~charge related to Virginia Power’s contract termination with a non-utility generator;

•	The absence of a $100 million charge associated with litigation acquired in ~~services performed for Atlantic Coast Pipeline. These expenses are billed~~the SCANA Combination; and

•	The absence of a $62 million charge related to ~~Atlantic Coast Pipeline and do not significantly impact net income.~~the abandonment of a project at a Virginia Power electric generating facility.

~~Depreciation, depletion and amortization~~

Other income increased ~~29%, primarily due to property, plant and equipment acquired in the SCANA Combination, including amortization of NND Project costs.~~

~~Other taxes~~ ~~increased 37%, primarily due to the SCANA Combination.~~

~~Impairment of assets and other charges~~ ~~increased $73~~$449 million, primarily due to a charge associated with litigation acquired in the SCANA Combination ($38 million), the abandonment of certain property, plant and equipment ($26 million) and a $21 million charge for disallowance of Virginia Power state-regulated plant.

~~Other income~~ ~~decreased 54%, primarily due to a decrease~~an increase in net investment earnings on nuclear decommissioning trust funds ($~~124~~311 million) and the absence of a ~~gain on~~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 ~~sale~~cancellation of ~~Dominion Energy’s 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership ($87 million).~~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 ~~19%, primarily due~~borrowings in response to ~~debt acquired in the SCANA Combination net of debt redeemed in the first~~COVID-19 ($24 million) and ~~third quarters of 2019.~~increases for unrealized losses associated with freestanding derivatives ($23 million).

Income tax expense decreased ~~81%,~~$599 million, primarily due to ~~lower~~a larger pre-tax ~~income~~loss ($~~146~~683 million), ~~higher renewable energy investment tax credits~~partially offset by charges associated with the cancellation of the Atlantic Coast Pipeline Project and related Supply Header Project ($~~38 million) and the absence of impacts from the 2017 Tax Reform Act ($31~~81 million).

Noncontrolling interests ~~decreased 66%,~~increased $33 million, primarily due to the ~~acquisition~~sale of ~~the public~~a 25% noncontrolling limited partnership interest in ~~Dominion Energy Midstream~~Cove Point to Brookfield in ~~January~~December 2019.

Year-To-Date ~~2019~~2020 vs. ~~2018~~2019

Net revenue increased ~~17%~~21%, primarily reflecting:

•	~~A $741 million increase from the SCANA Combination, due to operations acquired ($1.8 billion)~~The absence of a ~~, partially offset by~~ ~~a $1.0~~$1.0 billion charge for refunds of amounts previously collected from retail electric customers of DESC for the NND ~~Project~~;

•	A $236 million increase from the Liquefaction Facility, including terminalling services provided to the export customers ($190 million), a decrease in credits associated with the start-up phase ($25 million) and regulated gas transportation contracts to serve the export customers ($23 million);

•	~~The absence of a $215 million charge associated with Virginia legislation enacted in March 2018 that required one-time rate credits of certain amounts to utility customers;~~Project;

•	A ~~$198~~$226 million increase from Virginia Power rate adjustment clauses; and

•	A $48 ~~million increase due to favorable pricing at merchant generation facilities; and~~

•

~~A $34~~ million decrease in Virginia Power electric capacity expense related to the annual PJM capacity performance market effective June 2019 ($3551 million) and a contract termination with a non-utility generator ($2513 million), partially offset by the ~~annual PJM capacity performance market effective June 2018~~expiration of various contracts ($2616 million).

These increases were partially offset by:

•

~~A $166~~An $83 million decrease in sales to electric utility retail customers from a decrease in cooling degree days during the ~~absence of certain merchant generation facilities sold~~cooling season ($60 million) and a net decrease in ~~2018;~~heating degree days during the heating season ($23 million);

•	A ~~$75~~$61 million decrease due 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;~~Pipeline.

Other operations and maintenance decreased 11%, primarily reflecting:

•	The absence of a charge related to a voluntary retirement program ($288 million);

•	A ~~$33 million~~ decrease in sales to Virginia Power retail customers from lower heating degree days during the heating season, partially offset by a $25 million increase from higher cooling degree days during the cooling season; and

•	~~A $30 million decrease due to an increase in planned outage days at certain merchant generation facilities.~~

~~Other operations and maintenance~~ ~~increased 35%, primarily reflecting:~~

•	~~A $539 million increase from operations acquired in the SCANA Combination;~~

•	~~An increase~~ in merger and integration-related costs associated with the SCANA Combination ($~~435 million), including a charge related to a voluntary retirement program ($291~~96 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 ~~gains related to agreements to convey shale development rights under natural gas storage fields ($115 million);~~

•	~~A $45 million increase from additional planned outage days at certain generation facilities;~~

•	~~A $44 million increase in certain Virginia Power transmission-related expenditures. These expenses are primarily recovered through state and FERC rates and do not impact net income; and~~

•	~~A $25 million increase in operating expenses from the commercial operations of the Liquefaction Project and costs associated with regulated gas transportation contracts to serve the export customers.~~

~~These increases were partially offset by:~~

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

•	~~The absence of an $81 million charge associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018;~~

•

A ~~$74~~$55 million ~~decrease~~increase in ~~services performed for Atlantic Coast Pipeline. These expenses~~certain Virginia Power expenditures, which are ~~billed to Atlantic Coast Pipeline~~primarily recovered through state and FERC rates and do not ~~significantly~~ impact net ~~income;~~income; and

•	A ~~$33~~$22 million ~~decrease from~~increase in allowance for credit risk on customer accounts related to the ~~absence~~effects of ~~certain merchant generation facilities sold in 2018.~~COVID-19.

Depreciation, depletion and amortizationincreased ~~34%~~3%, primarily due to ~~property, plant and equipment acquired in the SCANA Combination ($421 million), including amortization of NND Project costs ($92 million), an increase from~~ various ~~growth~~ projects being placed into service ($~~112~~59 million)~~, including the Liquefaction Facility ($28 million), and~~ partially offset by the absence of ~~a benefit for the retroactive application of~~ depreciation ~~rates for regulated nuclear plants~~from certain electric generation facilities that were, or have been committed to ~~comply with Virginia Commission requirements~~be retired early ($~~31 million).~~

~~Other taxes~~ ~~increased 51%, primarily due to the SCANA Combination ($215~~25 million) and a ~~charge related to a voluntary retirement program~~decrease reflecting the expected approval of the nuclear plant life extensions from the NRC ($2416 million).

Impairment of assets and other charges increased ~~$1.1 billion,~~13%, primarily due to:

•	A ~~$368~~$482 million charge associated with the probable abandonment of portions of the Supply Header Project related to the ~~early retirement of certain Virginia Power electric generation facilities;~~Atlantic Coast Pipeline Project;

•	~~Charges~~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 ($~~316~~278 million);

•	AThe absence of a $160 million charge related to Virginia Power’s planned early retirement of certain automated meter reading infrastructure;

•	AThe absence of a $135 million charge related to Virginia Power’s contract termination with a non-utility generator;

•	A ~~$105 million charge~~decrease in charges for property, plant and equipment acquired in the SCANA Combination for which Dominion Energy committed to forgo ~~recovery;~~recovery ($103 million); and

•	AThe absence of a $62 million charge related to the abandonment of a project at a Virginia Power electric generating ~~facility; and~~

•	~~The abandonment of certain property, plant and equipment ($39 million); partially offset by~~

•	~~The absence of a $135 million charge for disallowance of FERC-regulated plant.~~facility.

Other income ~~remained substantially unchanged,~~decreased 88%, primarily reflectingnet investment losses in 2020 compared to net investment gains in 2019 on nuclear decommissioning trust funds ($481 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), the absence of a gain on the sale of Dominion Energy’s 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership ($87 million) and the absence of equity earnings due to the sale of Blue Racer in December 2018 ($40 million). These decreases were substantially offset by an increase in net investment earnings on nuclear decommissioning trust funds ($210 million) and an increase in non-service components of pension and other postretirement employee benefit plan credits ($26 million).

Earnings (loss) from equity ~~earnings from~~method investees decreased $2.3 billion, primarily due to charges associated with the cancellation of the Atlantic Coast Pipeline ~~($42 million).~~Project.

Interest and related chargesincreased ~~30%~~2%, primarily ~~due~~related to ~~debt acquired in~~increases for unrealized losses associated with freestanding derivatives ($81 million), charges associated with the ~~SCANA Combination net~~early redemption of ~~debt redeemed~~certain securities in the first quarter of 2020 ($25 million) and ~~third quarters of 2019~~increased borrowings in response to COVID-19 ($~~245~~24 million), ~~the absence of capitalization of~~partially offset by lower interest expense ~~associated with the Liquefaction Facility upon completion~~from early redemptions of ~~construction~~certain securities in 2019 and 2020 ($4694 million) and ~~higher long-term debt interest expense resulting from net debt issuances~~reductions in ~~2018~~commercial paper borrowings ($3217 million).

Income tax expense decreased ~~57%~~$732 million, primarily due to ~~lower~~a larger pre-tax ~~income~~loss ($~~452~~623 million) and the absence of ~~impacts from the 2017 Tax Reform Act ($31 million), partially offset by~~ a charge for certain income tax-related regulatory assets acquired 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 ~~the absence of a state legislative change~~related Supply Header Project ($2081 million).

Noncontrolling interests ~~decreased 79%,~~increased $61 million, primarily due to the ~~acquisition~~sale of ~~the public~~a 25% noncontrolling limited partnership interest in ~~Dominion Energy Midstream~~Cove Point to Brookfield in ~~January~~December 2019.

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, Dominion Energy realigned its segments which resulted in the formation of five primary operating segments. 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

2019

2018

$ Change

2019

2018

$ Change

(millions, except EPS)

Third Quarter

Power Delivery

$
185

$
163

$
22

$
0.23

$
0.25

$
(0.02
)
Power Generation

490

414

76

0.60

0.63

(0.03
)
Gas Infrastructure

232

264

(32
)

0.29

0.40

(0.11
)
Southeast Energy

147

—

147

0.18

—

0.18

Primary operating segments

1,054

841

213

1.30

1.28

0.02

Corporate and Other

(79
)

13

(92
)

(0.13
)

0.02

(0.15
)
Consolidated

$
975

$
854

$
121

$
1.17

$
1.30

$
(0.13
)

Year-To-Date

Power Delivery

$
496

$
464

$
32

$
0.62

$
0.71

$
(0.09
)
Power Generation

1,048

1,038

10

1.30

1.59

(0.29
)
Gas Infrastructure

838

840

(2
)

1.04

1.29

(0.25
)
Southeast Energy

361

—

361

0.45

—

0.45

Primary operating segments

2,743

2,342

401

3.41

3.59

(0.18
)
Corporate and Other

(2,394
)

(536
)

(1,858
)

(3.02
)

(0.82
)

(2.20
)
Consolidated

$
349

$
1,806

$
(1,457
)

$
0.39

$
2.77

$
(2.38
)

	Net Income (Loss) Attributable to Dominion Energy									Diluted EPS
	2020			2019			$ Change			2020			2019			$ Change
(millions, except EPS)
Second Quarter
Dominion Energy Virginia	$	437		$	393		$	44		$	0.52		$	0.49		$	0.03
Gas Transmission & Storage		184			177			7			0.22			0.22			(0.00	)
Gas Distribution		87			66			21			0.10			0.08			0.02
Dominion Energy South Carolina		75			95			(20	)		0.09			0.12			(0.03	)
Contracted Generation		21			13			8			0.03			0.02			0.01
Corporate and Other		(1,973	)		(690	)		(1,283	)		(2.37	)		(0.88	)		(1.49	)
Consolidated	$	(1,169	)	$	54		$	(1,223	)	$	(1.41	)	$	0.05		$	(1.46	)

Year-To-Date
Dominion Energy Virginia	$	866		$	754		$	112		$	1.03		$	0.95		$	0.08
Gas Transmission & Storage		405			399			6			0.48			0.50			(0.02	)
Gas Distribution		312			271			41			0.37			0.34			0.03
Dominion Energy South Carolina		169			166			3			0.20			0.21			(0.01	)
Contracted Generation		80			115			(35	)		0.10			0.14			(0.04	)
Corporate and Other		(3,271	)		(2,331	)		(940	)		(3.93	)		(2.92	)		(1.01	)
Consolidated	$	(1,439	)	$	(626	)	$	(813	)	$	(1.75	)	$	(0.78	)	$	(0.97	)

~~Power Delivery~~

Dominion Energy Virginia

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

	Third Quarter							Year-To-Date							Second Quarter							Year-To-Date
	2019		2018		% Change			2019		2018		% Change			2020		2019		% Change			2020		2019		% Change
Electricity delivered (million MWh)		24.4		24.0		2	%		66.8		67.0	—%				18.7		20.6		(9	)%		39.5		42.4		(7	)%
Degree days (electric distribution service area):
Electricity supplied (million MWh):
Utility																20.1		20.9		(4	)		42.5		42.8		(1	)
Degree days (electric distribution and utility service area):
Cooling		1,299		1,271		2			1,948		1,890		3			438		644		(32	)		452		649		(30	)
Heating		—		—		—			2,042		2,306		(11	)		371		150		147			1,889		2,042		(7	)
Average electric distribution customer accounts (thousands)⁽¹⁾		2,629		2,603		1			2,623		2,597		1
Average electric distribution customer accounts (thousands)																2,656		2,622		1			2,652		2,620		1

~~(1)~~

~~Period average.~~

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

	Third Quarter 2019 vs. 2018 Increase (Decrease)						Year-To-Date 2019 vs. 2018 Increase (Decrease)						Second Quarter 2020 vs. 2019 Increase (Decrease)						Year-To-Date 2020 vs. 2019 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	7		$	0.01		$	(2	)	$	—		$	(22	)	$	(0.03	)	$	(48	)	$	(0.06	)
Other		2			—			7			0.01			(15	)		(0.02	)		(11	)		(0.01	)
Rate adjustment clause equity return		17			0.02			40			0.06			32			0.04			55			0.07
Storm damage and service restoration		5			0.01			(5	)		(0.01	)
Electric capacity														9			0.01			33			0.04
Outages														14			0.02			22			0.02
Salaries, wages and benefits														15			0.02			26			0.03
Depreciation and amortization														9			0.01			21			0.02
Renewable energy investment tax credits														(10	)		(0.01	)		19			0.02
Other		(9	)		(0.01	)		(8	)		(0.01	)		12			0.01			(5	)		—
Share dilution		—			(0.05	)		—			(0.14	)		—			(0.02	)		—			(0.05	)
Change in net income contribution	$	22		$	(0.02	)	$	32		$	(0.09	)	$	44		$	0.03		$	112		$	0.08

~~Power Generation~~Gas Transmission & Storage

Presented below are selected operating statistics related to ~~Power Generation’s~~Gas Transmission & Storage’s operations:

Third Quarter

Year-To-Date

2019

2018

% Change

2019

2018

% Change

Electricity supplied (million MWh):

Utility

24.5

24.0

2
%

67.3

67.1

—%

Merchant

5.6

8.1

(31
)

15.2

23.1

(34
)
Degree days (electric utility service area):

Cooling

1,299

1,271

2

1,948

1,890

3

Heating

—

—

—

2,042

2,306

(11
)

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 ~~Power Generation’s~~Gas Transmission & Storage’s net income contribution:

Third Quarter
2019 vs. 2018
Increase (Decrease)

Year-To-Date
2019 vs. 2018
Increase (Decrease)

Amount

EPS

Amount

EPS

(millions, except EPS)

Regulated electric sales:

Weather

$
16

$
0.02

$
(3
)

$
—

Other

(3
)

—

(9
)

(0.01
)
Planned outage costs

3

—

(32
)

(0.05
)
Electric capacity

30

0.05

27

0.04

Sale of certain merchant generation facilities

(36
)

(0.05
)

(69
)

(0.11
)
Expiration of energy supply contract

13

0.02

22

0.03

Renewable energy investment tax credits

22

0.03

30

0.04

Interest expense

6

0.01

19

0.03

Other

25

0.04

25

0.04

Share dilution

—

(0.15
)

—

(0.30
)
Change in net income contribution

$
76

$
(0.03
)

$
10

$
(0.29
)

	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 ~~Infrastructure~~Distribution

Presented below are selected operating statistics related to Gas ~~Infrastructure’s~~Distribution’s operations:

	Third Quarter							Year-To-Date							Second Quarter							Year-To-Date
	2019		2018		% Change			2019		2018		% Change			2020		2019		% Change			2020		2019		% Change
Gas distribution throughput (bcf):
Sales		9		9	—%				92		85		8	%		24		24	—		%		104		112		(7	%)
Transportation		168		153		10			538		525		2			190		161		18			440		401		10
Heating degree days (gas distribution service area):
Eastern region		5		48		(90	)		3,446		3,633		(5	)
Western region		86		18		378			3,290		2,518		31
Average gas distribution customer accounts (thousands)⁽¹⁾:
North Carolina																314		155		103			1,648		1,811		(9	)
Ohio and West Virginia																804		526		53			3,246		3,441		(6	)
Utah, Wyoming and Idaho																547		634		(14	)		2,879		3,204		(10	)
Average gas distribution customer accounts (thousands):
Sales		1,273		1,253		2			1,271		1,254		1			1,885		1,846		2			1,888		1,847		2
Transportation		1,104		1,092		1			1,110		1,097		1			1,130		1,116		1			1,122		1,112		1
Average retail energy marketing customer accounts (thousands)⁽¹⁾		379		867		(56	)		375		864		(57	)

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

~~(1)~~

Second Quarter
2020 vs. 2019
Increase (Decrease)

Year-To-Date
2020 vs. 2019
Increase (Decrease)

Amount

EPS

Amount

EPS

(millions, except EPS)

Regulated gas sales:

Weather

$
3

$
—

$
(2
)

$
—

Other

1

—

12

0.01

Salaries, wages and benefits

8

0.01

12

0.02

Interest expense, net

5

0.01

11

0.01

Other

4

—

8

0.01

Share dilution

—

—

—

(0.02
)
Change in net income contribution

$
21

$
0.02

$
41

$
0.03

Dominion Energy South Carolina

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

	Second Quarter							Year-To-Date
	2020		2019		% Change			2020		2019		% Change
Electricity delivered (million MWh)		5.2		5.8		(10	%)		10.3		10.9		(6	%)
Electricity supplied (million MWh)		5.4		6.2		(13	)		10.7		11.4		(6	)
Degree days (electric distribution service areas):
Cooling		171		268		(36	)		176		268		(34	)
Heating		32		38		(16	)		610		698		(13	)
Average electric distribution customer accounts (thousands)		750		738		2			748		736		2
Gas distribution throughput (bcf):
Sales		14		15		(7	)		33		33		—
Average gas distribution customer accounts (thousands)		397		385		3			396		383		3

~~Period average.~~

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

Third Quarter
2019 vs. 2018
Increase (Decrease)

Year-To-Date
2019 vs. 2018
Increase (Decrease)

Amount

EPS

Amount

EPS

(millions, except EPS)

Cove Point export contracts

$
10

$
0.01

$
158

$
0.24

Noncontrolling interest⁽¹⁾

15

0.03

45

0.07

Interest expense, net

(8
)

(0.01
)

(72
)

(0.11
)
Assignment of shale development rights

(47
)

(0.07
)

(83
)

(0.13
)
State legislative change

—

—

(18
)

(0.03
)
Other

(2
)

—

(32
)

(0.05
)
Share dilution

—

(0.07
)

—

(0.24
)
Change in net income contribution

$
(32
)

$
(0.11
)

$
(2
)

$
(0.25
)

~~(1)~~

~~Reflects the acquisition of the public interest in Dominion Energy Midstream in January 2019.~~

	Second Quarter 2020 vs. 2019 Increase (Decrease)						Year-To-Date 2020 vs. 2019 Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(23	)	$	(0.03	)	$	(14	)	$	(0.02	)
Other		(4	)		—			1			—
Regulated gas sales		2			—			6			0.01
Regulatory rider equity return		(4	)		—			(4	)		(0.01	)
Interest expense, net		2			—			10			0.01
Other		7			0.01			4			0.01
Share dilution		—			(0.01	)		—			(0.01	)
Change in net income contribution	$	(20	)	$	(0.03	)	$	3		$	(0.01	)

~~Southeast Energy~~

Contracted Generation

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

Third Quarter

Year-To-Date

2019

2019

Electricity delivered (million MWh)

6.8

17.7

Electricity supplied (million MWh)

7.2

18.6

Degree days (electric distribution service area):

Cooling

645

913

Heating

—

698

Average electric distribution customer accounts
   (thousands)⁽¹⁾

742

738

Gas distribution throughput (bcf):

Sales

18

80

Transportation

17

48

Heating degree days (gas distribution service area)

—

808

Average gas distribution customer accounts
   (thousands)⁽¹⁾

964

963

Average retail energy marketing customer accounts
   (thousands)⁽¹⁾

406

415

~~(1)~~

~~Period average.~~

	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	%

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

	Third Quarter 2019 vs. 2018 Increase (Decrease)				Year-To-Date 2019 vs. 2018 Increase (Decrease)				Second Quarter 2020 vs. 2019 Increase (Decrease)						Year-To-Date 2020 vs. 2019 Increase (Decrease)
	Amount		EPS		Amount		EPS		Amount			EPS			Amount			EPS
(millions, except EPS)
SCANA Combination	$	147	$	0.18	$	361	$	0.45
Margin									$	(6	)	$	(0.01	)	$	(50	)	$	(0.06	)
Planned outage costs										8			0.01			8			0.01
Renewable energy investment tax credits										7			0.01			7			0.01
Other										(1	)		—			—			—
Share dilution										—			—			—			—
Change in net income contribution	$	147	$	0.18	$	361	$	0.45	$	8		$	0.01		$	(35	)	$	(0.04	)

Corporate and Other

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

	Third Quarter									Year-To-Date									Second Quarter									Year-To-Date
	2019			2018			$ Change			2019			2018			$ Change			2020			2019			$ Change			2020			2019			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	(80	)	$	122		$	(202	)	$	(1,955	)	$	(188	)	$	(1,767	)	$	(1,906	)	$	(482	)	$	(1,424	)	$	(2,937	)	$	(1,817	)	$	(1,120	)
Specific items attributable to Corporate and Other segment		88			(26	)		114			(155	)		(65	)		(90	)		31			(83	)		114			(139	)		(301	)		162
Total specific items		8			96			(88	)		(2,110	)		(253	)		(1,857	)		(1,875	)		(565	)		(1,310	)		(3,076	)		(2,118	)		(958	)
Other corporate operations⁽¹⁾		(87	)		(83	)		(4	)		(284	)		(283	)		(1	)		(98	)		(125	)		27			(195	)		(213	)		18
Total net income (expense)	$	(79	)	$	13		$	(92	)	$	(2,394	)	$	(536	)	$	(1,858	)	$	(1,973	)	$	(690	)	$	(1,283	)	$	(3,271	)	$	(2,331	)	$	(940	)
EPS impact	$	(0.13	)	$	0.02		$	(0.15	)	$	(3.02	)	$	(0.82	)	$	(2.20	)	$	(2.37	)	$	(0.88	)	$	(1.49	)	$	(3.93	)	$	(2.92	)	$	(1.01	)

(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 ~~those~~the segments' performance or in allocating resources. See Note 2221 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.

Virginia Power

Results of Operations

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

	Third Quarter						Year-To-Date							Second Quarter						Year-To-Date
	2019		2018		$ Change		2019		2018		$ Change			2020		2019		$ Change		2020		2019		$ Change
(millions)
Net income	$	602	$	520	$	82	$	722	$	1,043	$	(321	)	$	490	$	100	$	390	$	210	$	120	$	90

Overview

~~Third~~Second Quarter ~~2019~~2020 vs. ~~2018~~2019

Net income increased ~~16%,~~$390 million, primarily due to ~~an increase in cooling degree days in~~ the ~~service territory, a decrease in net electric capacity expense and higher renewable energy investment tax credits. These increases were partially offset by increases in~~absence of charges related to a voluntary retirement program, a contract termination with a non-utility generator and the abandonment ~~and disallowance~~ of ~~certain property, plant and equipment.~~a project at an electric generating facility.

Year-To-Date ~~2019~~2020 vs. ~~2018~~2019

Net income ~~decreased 31%,~~increased $90 million, primarily due to the absence of charges ~~associated with~~related to the planned early retirement of ~~certain electric generation facilities and~~ 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.

Analysis of Consolidated Operations

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

	Second Quarter								Year-To-Date
	2020			2019		$ Change			2020			2019		$ Change
(millions)
Operating revenue	$	1,805		$	1,938	$	(133	)	$	3,735		$	3,903	$	(168	)
Electric fuel and other energy-related purchases		366			536		(170	)		858			1,132		(274	)
Purchased (excess) electric capacity		(8	)		13		(21	)		(17	)		46		(63	)
Net revenue		1,447			1,389		58			2,894			2,725		169
Other operations and maintenance		376			565		(189	)		794			844		(50	)
Depreciation and amortization		307			299		8			618			603		15
Other taxes		85			90		(5	)		172			175		(3	)
Impairment of assets and other charges		44			197		(153	)		808			743		65
Other income		52			16		36			—			53		(53	)
Interest and related charges		137			135		2			263			270		(7	)
Income tax expense		60			19		41			29			23		6

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

Second Quarter 2020 vs. 2019

Net revenue increased 4%, primarily reflecting:

•	A $98 million increase from rate adjustment clauses; and

•	A $16 million decrease 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); partially offset by

•	A $30 million decrease in sales to retail customers from a decrease in cooling degree days; and

•	A $24 million decrease in sales to retail customers associated with usage factors impacted by COVID-19.

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 ~~increases~~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%, primarily reflecting:

•	A $226 million increase from rate adjustment clauses; and

•

A $48 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 ~~and the absence of charges associated with Virginia legislation enacted in March 2018 and April 2018.~~

~~Analysis of Consolidated Operations~~

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

Third Quarter

Year-To-Date

2019

2018

$ Change

2019

2018

$ Change

(millions)

Operating revenue

$
2,264

$
2,232

$
32

$
6,167

$
5,809

$
358

Electric fuel and other energy-related purchases

559

648

(89
)

1,691

1,747

(56
)
Purchased (excess) electric capacity

(1
)

50

(51
)

45

87

(42
)
Net revenue

1,706

1,534

172

4,431

3,975

456

Other operations and maintenance

453

404

49

1,297

1,242

55

Depreciation and amortization

313

295

18

916

839

77

Other taxes

82

79

3

257

241

16

Impairment of assets and other charges

38

—

38

781

—

781

Other income

15

25

(10
)

68

49

19

Interest and related charges

138

130

8

408

388

20

Income tax expense

95

131

(36
)

118

271

(153
)

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

~~Third Quarter 2019 vs. 2018~~

~~Net revenue~~ ~~increased 11%~~($113 million), ~~primarily reflecting:~~

•	~~A $96 million increase from rate adjustment clauses;~~

•	A $40 million decrease in electric capacity expense related to the annual PJM capacity performance market effective June 2019 ($27 million) and a contract termination with a non-utility generator ($13 million); and

•	~~A $31 million increase in sales to retail customers, primarily due to an increase in cooling degree days during the cooling season.~~

~~Other operations and maintenance~~ ~~increased 12%, primarily reflecting~~ an increase in certain ~~transmission-related expenses. These~~ expenses ~~were~~which are primarily recovered through state and FERC rates and ~~did~~do not impact net ~~income.~~income ($55 million) and an increase in allowance for credit risk on customer accounts related to COVID-19 ($13 million).

Depreciation and amortization increased 6%2%, primarily due to various projects being placed into service ($2252 million), partially offset by the absence of depreciation from certain electric generation facilities ~~and automated meter reading infrastructure~~ that were, or have committed to be, retired early ($1125 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 ~~$38 million, reflecting charges related to a $21 million charge for disallowance of state-regulated plant and the abandonment of certain property, plant and equipment ($17 million).~~

~~Other income~~ ~~decreased 40%, primarily reflecting a decrease in net investment earnings on nuclear decommissioning trust funds.~~

~~Income tax expense~~ ~~decreased 27%~~9%, primarily due ~~to higher renewable energy investment tax credits.~~to:

~~Year-To-Date 2019 vs. 2018~~

~~Net revenue~~ ~~increased 11%, primarily reflecting:~~

•	~~The absence of a $215 million charge~~An increase in charges associated with ~~Virginia legislation enacted in March 2018 that required one-time rate credits~~the planned early retirements of certain ~~amounts to utility customers;~~

•	~~A $198 million increase from rate adjustment clauses;~~electric generation facilities ($379 million); and

•

~~A $34 million decrease~~An increase in dismantling costs associated with certain electric ~~capacity expense related to the annual PJM capacity performance market effective June 2019~~generation facilities ($3530 million) ~~and a contract termination with a non-utility generator ($25 million),~~ ; partially offset by ~~the annual PJM capacity performance market effective June 2018 ($26 million); partially offset by~~

•	A $33 million decrease in sales to retail customers from lower heating degree days during the heating season partially offset by a $25 million increase from higher cooling degree days during the cooling season.

~~Other operations and maintenance~~ ~~increased 4%, primarily reflecting:~~

•	~~A $190 million charge related to a voluntary retirement program; and~~

•	~~A $44 million increase in certain transmission-related expenses. These expenses were primarily recovered through state and FERC rates and did not impact net income; partially offset by~~

•	~~A $113 million benefit from the revision of future ash pond and landfill closure costs as a result of Virginia legislation enacted in March 2019; and~~

•	The absence of ~~an $81 million charge associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018.~~

~~Depreciation and amortization~~ ~~increased 9%, due to various projects being placed into service ($71 million) and the absence of~~ a benefit for the retroactive application of depreciation rates for regulated nuclear plants to comply with Virginia Commission requirements ($31 million), partially offset by the absence of depreciation from certain electric generation facilities and automated meter reading infrastructure that were retired early ($29 million).

~~Impairment of assets and other charges~~ ~~increased $781 million, primarily reflecting:~~

•	~~A $368 million charge related to the early retirement of certain electric generation facilities;~~

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

•	AThe absence of a $135 million charge related to contract termination with a non-utility generator; and

•	AThe absence of a $62 million charge related to the abandonment of a project at an electric generating ~~facility;~~

•	~~A $21 million charge for disallowance of state-regulated plant; and~~

•	~~A $17 million charge related to the abandonment of certain property, plant and equipment.~~facility.

Other income ~~increased 39%,~~decreased $53 million, primarily reflecting ~~an increase in~~ net investment ~~earnings~~losses in 2020 compared to net investment gains in 2019 on nuclear decommissioning trust funds.

Income tax expense ~~decreased 56%~~increased 26%, primarily due to ~~lower~~higher pre-tax income ($~~122~~25 million) ~~and~~, partially offset by higher ~~renewable energy~~ investment tax credits ($2619 million).

Dominion Energy Gas

Results of Operations

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

	Third Quarter							Year-To-Date							Second Quarter								Year-To-Date
	2019		2018		$ Change			2019		2018		$ Change			2020			2019		$ Change			2020			2019		$ Change
(millions)
Net income	$	92	$	136	$	(44	)	$	255	$	317	$	(62	)
Net income (loss) attributable to Dominion Energy Gas															$	(198	)	$	119	$	(317	)	$	(29	)	$	309	$	(338	)

Overview

~~Third~~Second Quarter ~~2019~~2020 vs. ~~2018~~2019

Net income attributable to Dominion Energy Gas decreased ~~32%,~~$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 ~~gains~~net income from discontinued operations related to ~~agreements to convey shale development rights under natural gas storage fields.~~

~~Year-To-Date 2019 vs. 2018~~

~~Net income decreased 20%, primarily due~~the Dominion Energy Gas Restructuring, partially offset by the absence of ~~gains related to agreements to convey shale development rights under natural gas storage fields and~~ 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 ~~for disallowance of FERC-regulated plant.~~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:

	Third Quarter									Year-To-Date									Second Quarter									Year-To-Date
	2019			2018			$ Change			2019			2018			$ Change			2020			2019			$ Change			2020			2019		$ Change
(millions)
Operating revenue	$	392		$	423		$	(31	)	$	1,303		$	1,408		$	(105	)	$	510		$	530		$	(20	)	$	1,066		$	1,096	$	(30	)
Purchased (excess) gas		5			(7	)		12			49			22			27
Purchased gas																				—			(3	)		3			8			9		(1	)
Other energy-related purchases		17			26			(9	)		62			88			(26	)		1			1			—			1			1		—
Net revenue		370			404			(34	)		1,192			1,298			(106	)		509			532			(23	)		1,057			1,086		(29	)
Other operations and maintenance		159			180			(21	)		547			572			(25	)		150			210			(60	)		315			386		(71	)
Depreciation and amortization		64			61			3			188			173			15			94			92			2			187			182		5
Other taxes		47			45			2			162			152			10			35			38			(3	)		77			78		(1	)
Impairment of assets and other charges		—			1			(1	)		13			127			(114	)		482			13			469			482			13		469
Gains on sales of assets		(7	)		(65	)		58			(7	)		(116	)		109
Earnings from equity method investee		3			4			(1	)		13			18			(5	)
Earnings from equity method investees																				8			9			(1	)		23			22		1
Other income		35			34			1			103			99			4			46			44			2			95			85		10
Interest and related charges		26			28			(2	)		77			79			(2	)		50			86			(36	)		108			173		(65	)
Income tax expense		27			56			(29	)		73			111			(38	)
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:

~~Third~~Second Quarter ~~2019~~2020 vs. ~~2018~~2019

Net revenue decreased 8%4%, primarily reflecting:

•	A ~~$26~~$9 million decrease in services performed for Atlantic Coast ~~Pipeline;~~

•	~~A $9 million increase in net fuel costs; and~~Pipeline,

•	A $6 million decrease in ~~NGL activities; partially offset by~~services provided to affiliates; and

•	A $7$5 million ~~increase in PIR program revenues.~~decrease due to DETI contract changes.

Other operations and maintenance decreased ~~12%, primarily due to a $26 million decrease in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income.~~

~~Gains on sales of assets~~ ~~decreased 89%, primarily due to the absence of gains related to agreements to convey shale development rights under natural gas storage fields.~~

~~Income tax expense~~ ~~decreased 52%, primarily due to lower pre-tax income ($24 million) and the absence of impacts from the 2017 Tax Reform Act ($8 million).~~

~~Year-To-Date 2019 vs. 2018~~

~~Net revenue~~ ~~decreased 8%~~29%, primarily reflecting:

•	A ~~$75~~$39 million decrease ~~in services performed for Atlantic Coast Pipeline;~~

•	~~A $25 million increase in net fuel costs; and~~

•	~~A $16 million decrease in NGL activities; partially offset by~~

•	~~A $19 million increase in PIR program revenues.~~

~~Other operations and maintenance~~ ~~decreased 4% primarily reflecting:~~

•	~~A $74 million decrease in services performed for Atlantic Coast Pipeline. These expenses are billed~~due to ~~Atlantic Coast Pipeline and do not significantly impact net income; and~~

•	~~A $24 million benefit associated with~~the absence of a ~~revision of certain AROs; substantially offset by~~

•	~~A $59 million~~ charge related to a voluntary retirement program; and

•	A $7$9 million ~~increase~~decrease in ~~salaries, wages and benefits.~~services performed for Atlantic Coast Pipeline.

Impairment of assets and other charges ~~decreased 90%,~~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 ~~for disallowance of FERC-regulated plant ($127 million), partially offset by~~related to the abandonment of the Sweden Valley ~~project ($13 million).~~project.

~~Gains on sales of assets~~Interest and related charges decreased ~~94%~~42%,primarily due to the absence of ~~gains related to agreements to convey shale development rights under natural gas storage fields.~~

~~Earnings~~interest expense from ~~equity method investee~~ ~~decreased 28%~~Cove Point’s term loan borrowings ($32 million), ~~primarily due to lower earnings from unsubscribed capacity as a result of a decrease in heating degree days at Iroquois.~~ partially offset by interest expense on Dominion Energy Gas’ November 2019 senior note issuance ($8 million).

Income tax expensedecreased ~~34%,~~$105 million, primarily due to lower pre-tax ~~income ($33 million)~~income.

Year-To-Date 2020 vs. 2019

Net revenue decreased 3%, primarily reflecting:

•	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 ~~impacts~~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 ~~the 2017 Tax Reform Act~~Cove Point’s term loan borrowings ($868 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 ~~September~~June 30, ~~2019,~~2020, Dominion Energy had ~~$3.5~~$5.7 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 1716 to the Consolidated Financial Statements for more information.

A summary of Dominion Energy’s cash flows is presented below:

	2019			2018			2020			2019
(millions)
Cash, restricted cash and equivalents at January 1	$	391		$	185		$	269		$	391
Cash flows provided by (used in):
Operating activities		3,709			3,711			3,136			2,313
Investing activities		(3,160	)		(3,369	)		(3,334	)		(1,833	)
Financing activities		(500	)		(140	)		671			(311	)
Net increase in cash, restricted cash and equivalents		49			202			473			169
Cash, restricted cash and equivalents at September 30	$	440		$	387
Cash, restricted cash and equivalents at June 30							$	742		$	560

Operating Cash Flows

Net cash provided by Dominion Energy’s operating activities ~~was substantially consistent as increases in property tax payments~~, ~~decreased customer deposits,~~ increased ~~interest payments, higher customer refunds, a contract termination payment~~$823 million, primarily due to ~~a non-utility generator and an increase in merger and integration-related costs associated with the SCANA Combination were substantially offset by~~ higher deferred fuel cost recoveries, ~~at Virginia Power,~~lower payments for income taxes, the ~~commencement~~absence of ~~commercial operations of the Liquefaction Facility~~a contract termination payment and ~~operations acquired from the SCANA Combination.~~net changes in working capital items.

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, ~~2018.~~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 ~~September~~June 30, ~~2019~~2020 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	$	88	$	—	$	88
Non-investment grade⁽²⁾		—		—		—		3		—		3
No external ratings:
Internally rated—investment grade⁽³⁾		48		—		48		117		—		117
Internally rated—non-investment grade⁽⁴⁾		13		—		13		7		—		7
Total⁽⁵⁾	$	149	$	—	$	149	$	215	$	—	$	215

(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 ~~36%~~29% of the total net credit exposure.

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

(3)	The five largest counterparty exposures, combined, for this category represented approximately ~~32%~~53% of the total net credit exposure.

(4)	The five largest counterparty exposures, combined, for this category represented approximately 6%2% of the total net credit exposure.

(5)	Excludes ~~agreements approved by PURA, which commenced in October~~the Millstone 2019 ~~with Eversource Energy and The United Illuminating Company for Millstone to provide an estimated nine million MWh per year of electricity for ten years.~~power purchase agreements.

Investing Cash Flows

Net cash used in Dominion Energy’s investing activities ~~decreased $209 million,~~increased $1.5 billion, primarily due to ~~cash and restricted cash acquired in the SCANA Combination and proceeds from the sale of Blue Racer, partially offset by~~ an increase in plant construction and other property ~~additions.~~additions, 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, ~~2018,~~2019, 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 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 ~~used~~provided by Dominion Energy's financing activities ~~increased $360~~was $671 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 ~~net~~higher issuances of short- and long-term debt to buttress liquidity as a strategic response to COVID-19 and lower repayments ~~in 2019, compared to net~~of long-term debt, ~~issuances in 2018 and higher common dividend payments,~~ partially offset by higher ~~issuance~~repayments of ~~common stock~~short-term debt and the absence of the issuance of the 2019 Equity Units.

In November 2017, Dominion Energy filed ana SEC shelf registration statement 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 ~~September~~June 30, ~~2019~~2020 was ~~$26~~$176 million. The notes are short-term debt obligations on Dominion Energy’s Consolidated Balance Sheets. The proceeds will be used for general corporate purposes and to repay debt.

In ~~January 2019, Dominion Energy acquired all outstanding partnership interests~~July 2020, the Board of Directors authorized the repurchase of up to $3.0 billion of Dominion ~~Energy Midstream not owned by Dominion Energy through the issuance of 22.5 million common shares.~~

~~In January 2019, in connection with the SCANA Combination, Dominion Energy issued 95.6 million shares of Dominion Energy~~Energy’s common stock ~~valued~~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 ~~$6.8 billion, representing 0.6690~~any time. Shares may be purchased through open market or privately negotiated transactions or otherwise at the discretion of ~~a share of Dominion Energy common stock for each share of SCANA common stock outstanding at closing. SCANA’s outstanding debt totaled $6.9 billion at closing.~~

~~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.~~

~~In August 2019, Dominion Energy issued 18.5 million shares~~management subject to ~~settle the stock purchase contracts entered into as part of the 2016 Equity Units~~prevailing market conditions, applicable securities laws and ~~received proceeds of $1.4 billion.~~other factors.

See Note 1716 to the Consolidated Financial Statements in this report for further information regarding Dominion Energy’s credit facilities, liquidity and significant financing transactions.

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, ~~2018,~~2019, 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 ~~September~~June 30, ~~2019,~~2020, 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, ~~2018,~~2019, 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 ~~September~~June 30, ~~2019,~~2020, there have been no material changes to debt covenants, nor any events of default under Dominion Energy’s debt covenants.

Future Cash Payments for Contractual Obligations and Planned Capital Expenditures

As of ~~September~~June 30, ~~2019,~~2020, 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, ~~2018.~~2019.

Use of Off-Balance Sheet Arrangements

In August 2019, construction of the new corporate office property was substantially complete and the facility was able to be occupied resulting in the commencement of the five-year lease term. See Note 15 to the Consolidated Financial Statements in this report for additional information. As of ~~September~~June 30, ~~2019,~~2020, there have been no ~~other~~ material changes into the off-balance sheet arrangements disclosed in MD&A in the ~~Companies'~~Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019, with the exception of the following matter.

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 equity and has obtained financing commitments from debt investors, totaling $465 million, to fund 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 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, 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, ~~2018,~~2019, Future Issues and Other Matters in MD&A in the Companies’ Quarterly ~~Reports~~Report on Form 10-Q for the ~~quarters~~quarter ended March 31, ~~2019 and June 30, 2019~~2020 and Note 1817 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

22 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018,~~2019, Note 17 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, ~~2019,~~2020 and Note 1817 to the Consolidated Financial Statements ~~in the Companies’ Quarterly Report on Form 10-Q for the quarter ended June 30, 2019 and Note 18~~ in this report for additional information on various environmental matters.

Legal Matters

See Notes 3, 13 and 2223 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2018,~~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 the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2019, Notes 13 and 18 to the Consolidated Financial Statements and~~ ~~Item 1. Legal Proceedings~~ ~~in the Companies’ Quarterly Report on Form 10-Q for the quarter ended June 30, 2019 and Notes 13 and 18 to the Consolidated Financial Statements~~ 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, ~~2018,~~2019, Note 13 to the Consolidated Financial Statements in the Companies’ Quarterly ~~Reports~~Report on Form 10-Q for the ~~quarters~~quarter ended March 31, ~~2019 and June 30, 2019~~2020 and Note 13 to the Consolidated Financial Statements in this report for additional information on various regulatory matters.

~~Atlantic Coast Pipeline~~

~~In September 2014, Dominion Energy, along with Duke and Southern Company Gas, announced the formation of Atlantic Coast Pipeline.~~ Atlantic Coast Pipeline ~~is focused on constructing an approximately 600-mile natural gas pipeline running from West Virginia through Virginia to North Carolina.~~and Supply Header Projects

In July 2020, Dominion Energy and Duke Energy announced the cancellation of the Atlantic Coast Pipeline ~~has continued to experience delays in obtaining permits necessary~~Project. As a result, Dominion Energy recorded an abandonment for ~~construction along with construction delays due to judicial actions. In October 2019, the Supreme Court~~a significant portion of the U.S. agreed to hear Atlantic Coast Pipeline’s request to hear the case regarding the Appalachian Trail crossing. The Supreme Court of the U.S. is expected to issue a ruling by June 2020. Atlantic Coast Pipeline is also evaluating possible legislative remedies to this issue. Given the legal challengesSupply Header Project. See Notes 2 and ongoing discussions with customers, project construction is expected to be completed by the end of 2021, with full in-service in early 2022. Project cost estimates are $7.3 billion to $7.8 billion, excluding financing costs. Project construction activities, schedules and costs are subject to uncertainty due to permitting and/or work delays (including due to judicial or regulatory action), abnormal weather and other conditions that could result in cost or schedule modifications in the future, a suspension of AFUDC for Atlantic Coast Pipeline and/or impairment charges potentially material to Dominion Energy’s cash flows, financial position and/or results of operations. See Note 10 to the Consolidated Financial Statements in this report for more information.

~~Supply Header Project~~NWP 12 Permitting

In ~~December 2014, DETI entered~~April 2020, the U.S. District Court for the District of Montana issued an order vacating an NWP 12 issued by the Army Corps 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 ~~precedent agreement with~~result of the amended order, the cancellation of the Atlantic Coast Pipeline ~~for~~Project and the ~~Supply Header project, a project~~pending sale of its gas transmission operations to provide approximately 1,500,000 Dths per day of firm transportation service to various customers. Atlantic Coast Pipeline has continued to experience delays in obtaining permits necessary for construction and delays in construction due to judicial actions. As a result, project cost estimates are $725 million to $775 million, excluding financing costs. Project construction is expected to be completed by the end of 2021 with full in-service in early 2022.

~~Millstone Agreement~~

In November 2017, Connecticut adopted the Act Concerning Zero Carbon Solicitation and Procurement, which allows nuclear generating facilities to compete for power purchase agreements in a state sponsored procurement for electricity. In February 2018, Connecticut regulators recommended pursuing the procurement. In May 2018, Millstone petitioned to be considered an “existing resource confirmed at risk” and subsequently participated in the state sponsored procurement for electricity. Being considered “at risk” allows the Department of Energy and Environmental Protection to consider factors other than price, such as environmental and economic benefits, when evaluating Dominion Energy’s bids. In December 2018, PURA confirmed that Millstone should be considered an “existing resource confirmed at risk” in the state’s Department of Energy and Environmental Protection zero carbon procurement. An agreement was reached in March 2019 betweenBHE, Dominion Energy ~~Eversource Energy and The United Illuminating Company for Millstone~~does not currently expect this matter to ~~provide nine million MWh per year~~have a material impact to its results of ~~electricity for ten years. In September 2019, PURA approved the agreement, which commenced in October 2019.~~operations, financial position or cash flows.

COVID-19

~~Coastal Virginia Offshore Wind Project~~Dominion Energy continues to monitor the global outbreak of COVID-19 and has taken appropriate steps to mitigate the potential risks to Dominion Energy, its employees and its customers posed by the spread of the virus. 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 ~~November 2018, Virginia Power received approval~~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 aspects of its business, such as construction projects, and will take additional precautions as Dominion Energy believes are warranted. In addition, Dominion Energy continues 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 Virginia Commission to develop two 6 MW wind turbines off the coast of Virginia for the Coastal Virginia Offshore Wind project, expected to cost approximately $300 million and to be in service in late 2020. In September 2019, Virginia Power filed an application with PJM to interconnect 2,640 MW of wind energy between 2024 and 2026 off the coast of Virginia as an expansionimpacts of the ~~Coastal Virginia Offshore Wind project, expected to increase~~COVID-19 pandemic on its operations, the ~~total cost by up to approximately $8 billion.~~

~~Align RNG~~

~~In November 2018, Dominion Energy announced~~ultimate impacts on its results of operations, financial position and/or cash flows could be material based on the ~~formation~~ultimate duration of Align RNG, an equal partnership with Smithfield Foods, Inc. As announced in October 2019, Align RNG expects to invest $500 million to develop assets to capture methane from hog farms across Virginia, North Carolina, Utah, Arizonathe pandemic and ~~California and convert it into pipeline quality natural gas.~~ the related economic recovery.

ITEM 3.

QUANTITATIVE AND QUALITATIVE

DISCLOSURES ABOUT MARKET RISK

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

Market Risk Sensitive Instruments and Risk Management

The Companies’ financial instruments, commodity contracts and related financial derivative instruments are exposed to potential losses due to adverse changes in commodity prices, interest rates and equity security prices as described below. Commodity price risk is present in Dominion Energy and Virginia Power’s electric operations and Dominion Energy and Dominion Energy Gas’ 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 hold commodity-based derivative instruments held for non-trading purposes associated with purchases and sales of electricity, natural gas and other energy-related ~~products and~~products. Dominion Energy Gas’ operations are contracted primarily under long-term fixed reservation agreements. Accordingly, management believes that Dominion Energy Gas ~~holds commodity-based financial derivative instruments held for non-trading purposes associated with sales of NGLs.~~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 ~~$59~~$31 million and $6$50 million of Dominion Energy’s commodity-based derivative instruments as of ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively. ~~The increase in sensitivity is largely due to decreased short positions and lower commodity prices on those short positions.~~

A hypothetical 10% decrease in commodity prices would have resulted in a decrease in fair value of ~~$61~~$42 million and ~~$51~~$54 million of Virginia Power’s commodity-based derivative instruments as of ~~September~~June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively.

A hypothetical 10% increase in commodity prices would not have resulted in a material change of Dominion Energy Gas’ commodity-based derivative instruments as of both September 30, 2019 and December 31, 2018.

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, a hypothetical 10% increase in market interest rates would result in a $22 million and $24 million decrease in earnings at September 30, 2019 and December 31, 2018, respectively. For variable rate debt outstanding for 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 ~~September~~June 30, ~~2019~~2020 or December 31, ~~2018.~~2019.

The Companies also use interest rate derivatives, including forward-starting swaps, as ~~cash flow~~ hedges of forecasted interest payments. As of ~~September~~June 30, ~~2019,~~2020, Dominion Energy, Virginia Power and Dominion Energy Gas had ~~$5.5~~$8.5 billion, ~~$1.8~~$2.1 billion and $1.3 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 ~~$120~~$95 million, ~~$77~~$50 million and ~~$14~~$7 million, respectively, in the fair value of Dominion Energy, Virginia Power and Dominion Energy Gas’ interest rate derivatives at ~~September~~June 30, ~~2019.~~2020. As of December 31, ~~2018,~~2019, Dominion Energy, Virginia Power and Dominion Energy Gas had ~~$5.9~~$6.4 billion, $1.9 billion and ~~$1.1~~$1.3 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 ~~$147~~$135 million, ~~$94~~$88 million and $17 million, respectively, in the fair value of Dominion Energy, Virginia Power and Dominion Energy Gas’ interest rate derivatives at December 31, ~~2018.~~2019.

Dominion Energy Gas holds foreign currency swaps for the purpose of hedging the foreign currency exchange risk associated with Euro denominated debt. ~~As of September~~At both June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, Dominion Energy and Dominion Energy Gas had ~~$280~~€250 million ~~(€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 ~~September~~June 30, ~~2019 and would have resulted in a decrease of $8 million in the fair value of Dominion Energy Gas' foreign currency swaps at~~2020 or December 31, ~~2018.~~2019.

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 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 Consolidated Balance Sheets at fair value.

Dominion Energy recognized net investment ~~gains on nuclear decommissioning and rabbi trust investments of $691 million and $350 million for the nine months ended September 30, 2019 and 2018, respectively, and net investment~~ losses (including investment income) on nuclear decommissioning and rabbi trust investments of ~~$135~~$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 million for the six months ended June 30, 2019 and $1.0 billion for the year ended December 31, ~~2018.~~2019. 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.~~value in 2019 only. Dominion Energy recorded in AOCI and regulatory liabilities, a net increase in unrealized gains on debt investments of ~~$73~~$37 million and $65 million for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, respectively, and ~~recorded a net decrease in unrealized gains on debt investments of $36 million and an additional unrealized loss of $10 million for the nine months ended September 30, 2018 and $36~~$74 million for the year ended December 31, ~~2018.~~2019.

Virginia Power recognized ~~net investment gains on nuclear decommissioning trust investments of $335 million and $163 million for the nine months ended September 30, 2019 and 2018, respectively, and~~ net investment losses (including investment income) on nuclear decommissioning and rabbi trust investments of ~~$44~~$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 million for the year ended December 31, ~~2018.~~2019. 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.~~value in 2019 only. Virginia Power recorded in AOCI and regulatory liabilities, a net increase in unrealized gains on debt investments of ~~$35~~$20 million and $31 million for the ~~nine~~six months ended ~~September~~June 30, 2020 and 2019, respectively, and ~~recorded a net decrease in unrealized gains on debt investments of $19 million with an additional unrealized loss of $5 million for the nine months ended September 30, 2018 and $21~~$30 million for the year ended December 31, ~~2018.~~2019.

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 Dominion Energy, Virginia Power and Dominion Energy Gas, including Dominion Energy, Virginia Power and Dominion Energy Gas’ 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, Virginia Power and Dominion Energy Gas’ 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, Virginia Power or Dominion Energy Gas’ internal control over financial reporting.

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

From time to time, the Companies are alleged to be in violation 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. Administrative proceedings may also be pending on these matters. In addition, in the ordinary course of business, the Companies and their subsidiaries are involved in various legal 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 3, 13 and 2223 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, ~~2018.~~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, ~~2019.~~2020.

•	Notes 13 and 1817 to the Consolidated Financial Statements in ~~the Companies’ Quarterly Report on Form 10-Q for the quarter ended June 30, 2019.~~this report.

•

~~Notes 13~~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 18are 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 ~~Consolidated Financial Statements~~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 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, 2018, 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, 2018. 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

Period

Total
Number of
Shares
(or Units)
Purchased⁽¹⁾

Average
Price Paid
per Share
(or Unit)⁽²⁾

Total Number
of Shares (or Units)
Purchased as Part
of Publicly
Announced Plans or
Programs

Maximum Number (or
Approximate Dollar
Value) of Shares (or Units)
that May Yet Be
Purchased under the Plans
or Programs⁽³⁾
7/1/19-7/31/19

2,002

$
77.47

—

19,629,059 shares/
$1.18 billion
8/1/19-8/31/19

146

77.05

—

19,629,059 shares/
$1.18 billion
9/1/19-9/30/19

5,613

78.49

—

19,629,059 shares/
$1.18 billion
Total

7,761

$
78.20

—

19,629,059 shares/
$1.18 billion

Period

Total

Number of

(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

(1)	~~In July, August and September 2019, 2,002~~Represents shares ~~146 shares and 5,613 shares, respectively,~~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 the Dominion Energy Board of Directors in February 2005, as modified in June 2007. The aggregate authorization granted by the Dominion Energy Board of Directors was 86 million shares (as adjusted to reflect a two-for-one stock split distributed in November 2007) not to exceed $4 billion.

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).	X

3.1.a	Dominion Energy, Inc. Articles of Incorporation, as restated, effective ~~September 27,~~December 13, 2019 (Exhibit 3.1, Form 8-K filed ~~October 2,~~December 13, 2019, File No.1-8489).	X

3.1.b	Virginia Electric and Power Company Amended and Restated Articles of Incorporation, as in effect on October 30, 2014 (Exhibit 3.1.b, Form 10-Q filed November 3, 2014, File No. 1-2255).		X

3.1.c	Articles of Organization of Dominion Energy Gas Holdings, LLC (Exhibit 3.1, Form S-4 filed April 4, 2014, File No. 333-195066).			X

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).			X

3.2.a	Dominion Energy, Inc. Bylaws, as amended and restated, effective ~~September 26, 2019~~July 30, 2020 (Exhibit ~~3.2,~~3.1, Form 8-K filed ~~October 2, 2019,~~July 31, 2020, File No. 1-8489).	X

3.2.b	Virginia Electric and Power Company Amended and Restated Bylaws, effective June 1, 2009 (Exhibit 3.1, Form 8-K filed June 3, 2009, File No. 1-2255).		X

3.2.c	Operating Agreement of Dominion Energy Gas Holdings, LLC, ~~dated~~ as ~~of May 12, 2017~~amended and restated, effective November 5, 2019 (Exhibit ~~3.2,~~3.1, Form 8-K filed ~~May 16, 2017,~~November 12, 2019, File No. 001-37591).			X

4.1	Dominion Energy, Inc., 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.	X	X	X

~~Exhibit~~

~~Number~~

~~Description~~

~~Dominion Energy~~

~~Virginia Power~~

~~Dominion Energy Gas~~

4.2

Exhibit Number	Description	Dominion Energy	Virginia Power
~~4.3~~	Senior Indenture, dated as of September 1, 2017, between Virginia Electric and Power Company and U.S. Bank National Association, as Trustee (Exhibit 4.1, Form 8-K filed September 13, 2017, File No.000-55337); ~~First Supplemental Indenture, dated as of September 1, 2017 (Exhibit 4.2, Form 8-K filed September 13, 2017, File No.000-55337)~~; ~~Second Supplemental Indenture, dated as of March 1, 2018 (Exhibit 4.2, Form 8-K filed March 22, 2018, File No. 000-55337)~~; ~~Third Supplemental Indenture, dated as of November 1, 2018 (Exhibit 4.2, Form 8-K filed November 28, 2018, File No. 000-55337)~~; ~~Fourth Supplemental Indenture, dated as of July 1, 2019 (Exhibit 4.2, Form 8-K filed July 10, 2019, File No. 000-55337)~~.		X

~~10.1~~	Dominion Resources, Inc. New Executive Supplemental Retirement Plan, as amended and restated effective July 1, 2013 (Exhibit 10.2, Form 10-Q for the quarter ended June 30, 2013 filed August 6, 2013 File No. 1-8489), ~~as amended September 26, 2014 (Exhibit 10.3, Form 10-Q for the fiscal quarter ended September 30, 2014 filed November 3, 2014)~~, ~~as amended effective October 1, 2019 (Exhibit 10.1, Form 8-K filed October 2, 2019, File No. 1-8489)~~.	X	X	XEnergy 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).	X

31.b	Certification by Chief Financial Officer of Dominion Energy, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X

31.c	Certification by Chief Executive Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X

31.d	Certification by Chief Financial Officer of Virginia Electric and Power Company pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).		X

~~Exhibit~~ ~~Number~~	~~Description~~	~~Dominion Energy~~	~~Virginia Power~~	~~Dominion Energy Gas~~

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).			X

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).			X

32.a	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion Energy, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).	X

32.b	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Virginia Electric and Power Company as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).		X

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).			X

99	Condensed consolidated earnings statements (filed herewith).	X	X	X

101	The following financial statements from Dominion Energy, Inc.’s Quarterly Report on Form 10-Q for the quarter ended ~~September~~June 30, ~~2019,~~2020, filed on ~~November 1, 2019,~~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. The following financial statements from Virginia Electric and Power Company’s Quarterly Report on Form 10-Q for the quarter ended ~~September~~June 30, ~~2019,~~2020, filed on ~~November 1, 2019,~~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 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 ~~September~~June 30, ~~2019,~~2020, filed on ~~November 1, 2019,~~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.	X	X	X

104	Cover Page Interactive Data File formatted in iXBRL (Inline eXtensible Business Reporting Language) and contained in Exhibit 101.	X	X	X

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

~~November 1, 2019~~August 5, 2020	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

	VIRGINIA ELECTRIC AND POWER COMPANY Registrant

~~November 1, 2019~~August 5, 2020	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

	DOMINION ENERGY GAS HOLDINGS, LLC Registrant

~~November 1, 2019~~August 5, 2020	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

130

	Amount
(millions)
Total current assets⁽¹⁾		$	1,782
Investments			224
Property, plant and equipment⁽²⁾			11,006
Goodwill			2,576
Regulatory assets⁽³⁾			3,940
Other deferred charges and other assets, including intangible assets			430
Total Assets			19,958
Total current liabilities			1,515
Long-term debt			6,707
Deferred income taxes			1,114
Regulatory liabilities			2,668
Other deferred credits and other liabilities⁽⁴⁾			1,115
Total Liabilities			13,119
Total purchase price⁽⁵⁾		$	6,839

	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019
(millions)
Dominion Energy
Finance lease cost:
Amortization	$	7	$	14
Interest		1		3
Operating lease cost		20		64
Short-term lease cost		7		20
Variable lease cost		1		4
Total lease cost	$	36	$	105
Virginia Power
Operating lease cost	$	10	$	31
Short-term lease cost		3		7
Variable lease cost		1		2
Total lease cost	$	14	$	40
Dominion Energy Gas
Operating lease cost	$	3	$	10
Short-term lease cost		2		5
Total lease cost	$	5	$	15

Maturity of Lease Liabilities	Dominion Energy						Virginia Power						Dominion Energy Gas
(millions)	Operating			Finance			Operating			Finance			Operating			Finance
2019	$	18		$	10		$	8		$	1		$	5		$	1
2020		68			39			33			3			13			2
2021		61			33			29			3			11			2
2022		50			31			23			3			9			2
2023		40			28			18			2			6			2
After 2023		538			49			160			4			25			3
Total undiscounted lease payments		775			190			271			16			69			12
Present value adjustment		(323	)		(28	)		(89	)		(2	)		(13	)		(2	)
Present value of lease liabilities	$	452		$	162		$	182		$	14		$	56		$	10

	Gas Infrastructure		Corporate and Other			Consolidated Total
(millions)
Three Months Ended September 30, 2019
Operating revenue	$	392	$	—		$	392
Net income (loss)		100		(8	)		92
Three Months Ended September 30, 2018
Operating revenue	$	423	$	—		$	423
Net income (loss)		146		(10	)		136
Nine Months Ended September 30, 2019
Operating revenue	$	1,314	$	(11	)	$	1,303
Net income (loss)		316		(61	)		255
Nine Months Ended September 30, 2018
Operating revenue	$	1,408	$	—		$	1,408
Net income (loss)		421		(104	)		317

Period	Total Number of Shares (or Units) Purchased⁽¹⁾		Average Price Paid per Share (or Unit)⁽²⁾		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased under the Plans or Programs⁽³⁾
7/1/19-7/31/19		2,002	$	77.47		—	19,629,059 shares/ $1.18 billion
8/1/19-8/31/19		146		77.05		—	19,629,059 shares/ $1.18 billion
9/1/19-9/30/19		5,613		78.49		—	19,629,059 shares/ $1.18 billion
Total		7,761	$	78.20		—	19,629,059 shares/ $1.18 billion