UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended ~~September 30, 2018~~March 31, 2019

☐	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

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, smaller reporting company or emerging growth company. See the definitions of “large accelerated filer,” “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 ☒

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 DCUD DRUA	Common Stock, no par value 2016 Series A 6.75% Corporate Units 2016 Series A 5.25% Enhanced Junior Subordinated Notes	New York Stock Exchange New York Stock Exchange New York Stock Exchange
DOMINION ENERGY GAS HOLDINGS, LLC		2014 Series C 4.6% Senior Notes	New York Stock Exchange

At ~~October~~April 12, ~~2018,~~2019, the latest practicable date for determination, Dominion Energy, Inc. had ~~655,083,378~~802,364,338 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	34

	PART I. Financial Information

Item 1.	Financial Statements	79
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	9793
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	~~114~~107
Item 4.	Controls and Procedures	~~115~~108

	PART II. Other Information

Item 1.	Legal Proceedings	~~116~~109
Item 1A.	Risk Factors	~~116~~109
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	~~117~~109
Item 6.	Exhibits	~~117~~110

GLOSSARY OF TERMS

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

Abbreviation or Acronym		Definition
~~2014 Equity Units~~		~~Dominion Energy's 2014 Series A Equity Units issued in July 2014~~
2016 Equity Units		Dominion Energy's 2016 Series A Equity Units issued in August 2016
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
AFUDC		Allowance for funds used during construction
AMI		Advanced Metering Infrastructure
AMR		Automated meter reading program deployed by East Ohio
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, Duke and Southern Company Gas
BACT		Best available control technology
Bankruptcy Court		U.S. Bankruptcy Court for the Southern District of New York
bcf		Billion cubic feet
Blue Racer		Blue Racer Midstream, LLC, a joint venture between ~~Dominion Energy and~~ Caiman Energy II, LLC
~~Brunswick County~~		~~A 1,376 MW combined-cycle, natural gas-fired power station in Brunswick County, Virginia~~ and FR BR Holdings, LLC effective December 2018
CAA		Clean Air Act
CAISO		California Independent System Operator
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		An approximately 142 MW proposed utility-scale solar power station located in Surry County, Virginia
Companies		Dominion Energy, Virginia Power and Dominion Energy Gas, collectively
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~~Holdings		~~An LNG terminalling and storage facility located on the Chesapeake Bay in Lusby, Maryland owned by~~ Cove Point GP Holding Company, LLC
CPCN		Certificate of Public Convenience and Necessity
CWA		Clean Water Act
DECG		Dominion Energy Carolina Gas Transmission, LLC
DES		Dominion Energy Services, Inc.
DESC		Dominion Energy South Carolina, Inc. (formerly known as South Carolina Electric & Gas Company), its consolidated subsidiaries or operating segments, or the entirety of Dominion Energy South Carolina, Inc. and its consolidated subsidiaries

Abbreviation or Acronym		Definition
DETI		Dominion Energy Transmission, Inc.
DGI		Dominion Generation, Inc.
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

~~Abbreviation or Acronym~~		~~Definition~~
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 Midstream		The legal entity, Dominion Energy Midstream Partners, LP, one or more of its consolidated subsidiaries, Cove Point Holdings, Iroquois GP Holding Company, LLC, DECG and Dominion Energy Questar Pipeline, ~~or operating segment,~~ or the entirety of Dominion Energy Midstream Partners, LP and its consolidated subsidiaries
Dominion Energy Questar Pipeline		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
DSM		Demand-side management
Dth		Dekatherm
Duke		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
~~Eagle Solar~~		~~Eagle Solar, LLC, a wholly-owned subsidiary of Dominion Energy~~
East Ohio		The East Ohio Gas Company, doing business as Dominion Energy Ohio
~~Eastern Market Access Project~~		Project to provide 294,000 Dths/day of firm 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, and Mattawoman Energy, LLC for its new electric power generation facility to be built in Maryland
EPA		U.S. Environmental Protection Agency
EPS		Earnings per share
~~Fairless~~		~~Dominion Energy Fairless, LLC, which owns the Fairless power station~~
FASB		Financial Accounting Standards Board
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 between Dominion Energy and BP Wind Energy North America Inc. in Benton County, Indiana~~
FTRs		Financial transmission rights
GAAP		U.S. generally accepted accounting principles
Gal		Gallon
Gas Infrastructure		Gas Infrastructure Group operating segment
GHG		Greenhouse gas
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)~~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		GreenHat Energy, LLC
GTSA		Virginia Grid Transformation and Security Act of 2018
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

Abbreviation or Acronym		Definition
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 New England, Inc.

~~Abbreviation or Acronym~~		~~Definition~~
Kewaunee		Kewaunee nuclear power station
kV		Kilovolt
Liquefaction ~~Project~~Facility		A natural gas export/liquefaction facility at Cove Point
LNG		Liquefied natural gas
~~Manchester~~		~~Dominion Energy Manchester Street, Inc., which owns the Manchester power station~~
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
MW		Megawatt
MWh		Megawatt hour
NAV		Net asset value
~~NedPower~~		~~NedPower Mount Storm LLC, a wind-turbine facility joint venture between Dominion Energy and Shell Wind Energy, Inc. in Grant County, West Virginia~~
NGL		Natural gas liquid
NND Project		V.C. Summer Units 2 and 3 new nuclear development project under which SCANA and Santee Cooper undertook to construct two Westinghouse AP1000 Advanced Passive Safety nuclear units in Jenkinsville, South Carolina
North Carolina Commission		North Carolina Utilities Commission
NO_x		Nitrogen oxide
NRC		U.S. Nuclear Regulatory Commission
~~NRG~~		The legal entity, NRG Energy, Inc., one or more of its consolidated subsidiaries (including, through August 2018, Four Brothers, Granite Mountain and Iron Springs) or operating segments, or the entirety of NRG Energy, Inc. and its consolidated subsidiaries
NSPS		New Source Performance Standards
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		Percentage of Income Payment Plan deployed by East Ohio
PIR		Pipeline Infrastructure Replacement program deployed by East Ohio
PJM		PJM Interconnection, L.L.C.
Power Delivery		Power Delivery Group operating segment
Power Generation		Power Generation Group operating segment
ppb		Parts-per-billion
PSD		Prevention of ~~Significant Deterioration~~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

Abbreviation or Acronym		Definition
Regulation Act		Legislation effective July 1, 2007, that amended the Virginia Electric Utility Restructuring Act and fuel factor statute, which legislation is also known as the Virginia Electric Utility Regulation Act, as amended in 2015 and 2018
RICO		Racketeer Influenced and Corrupt Organizations Act
Rider BWU		A rate adjustment clause associated with the recovery of costs of new underground distribution facilities
Rider US-3		A rate adjustment clause associated with the recovery of costs related to ~~Brunswick County~~
~~Rider T1~~		~~A rate adjustment clause to recover the difference between revenues produced from transmission rates included in base rates,~~Colonial Trail West and ~~the new total revenue requirement developed annually for the rate years effective September~~Spring Grove 1
~~Rider US-2~~		~~A rate adjustment clause associated with the recovery of costs related to Woodland, Scott Solar and Whitehouse~~

~~Abbreviation or Acronym~~		~~Definition~~
Riders C1A, C2A and ~~C2A~~C3A		Rate adjustment clauses associated with the recovery of costs related to certain DSM programs ~~approved in~~ ~~DSM cases~~
ROE		Return on equity
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 ~~operating segments, 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 SCANA Merger Agreement
SCANA Merger Agreement		Agreement and plan of merger entered on January 2, 2018 between Dominion Energy and SCANA ~~in which SCANA will become a wholly-owned subsidiary of Dominion Energy upon closing~~
~~SCE&G~~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 ~~Electric & Gas Company, a wholly-owned subsidiary~~Department of ~~SCANA~~Health and Environmental Control
~~Scott Solar~~SCDOR		~~A 17 MW utility-scale solar power station in Powhatan County, Virginia~~South Carolina Department of Revenue
SEC		U.S. Securities and Exchange Commission
South Carolina Commission		Public Service Commission of South Carolina
Southeast Energy		Southeast Energy Group operating segment
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 ~~McGraw Hill Financial,~~S&P Global Inc.
Summer		V.C. Summer nuclear power station
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
~~UEX Rider~~		~~Uncollectible Expense Rider deployed by East Ohio~~
~~Utah Commission~~		~~Public Service Commission of Utah~~
VDEQ		Virginia Department of Environmental Quality
VEBA		Voluntary Employees' Beneficiary Association
VIE		Variable interest entity
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, or the entirety of Virginia Electric and Power Company and its consolidated subsidiaries
VOC		Volatile organic compounds
~~Whitehouse~~WECTEC		~~A 20 MW utility-scale solar power station in Louisa County, Virginia~~WECTEC Global Project Services, Inc. (formerly known as Stone & Webster, Inc.), a wholly-owned subsidiary of Westinghouse
~~Woodland~~Westinghouse		~~A 19 MW utility-scale solar power station in Isle~~Westinghouse Electric Company LLC
West Virginia Commission		Public Service Commission of ~~Wight County,~~West Virginia
White River Hub		White River Hub, LLC

Abbreviation or Acronym		Definition
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 March 31,
	2018		2017		2018		2017			2019			2018
(millions, except per share amounts)
Operating Revenue⁽¹⁾	$	3,451	$	3,179	$	10,005	$	9,376		$	3,858		$	3,466
Operating Expenses
Electric fuel and other energy-related purchases		761		638		2,128		1,711			791			744
Purchased (excess) electric capacity		50		21		87		(8	)
Purchased electric capacity											39			14
Purchased gas		5		24		409		441			730			340
Other operations and maintenance		782		697		2,585		2,308			1,002			795
Depreciation, depletion and amortization		526		485		1,487		1,421			651			498
Other taxes		177		162		542		519			292			199
Impairment of assets and other charges											835			1
Total operating expenses		2,301		2,027		7,238		6,392			4,340			2,591
Income from operations		1,150		1,152		2,767		2,984
Income (loss) from operations											(482	)		875
Other income		373		121		658		391			388			100
Interest and related charges		378		305		1,053		905			469			314
Income from operations including noncontrolling interests before income tax expense		1,145		968		2,372		2,470
Income (loss) from operations including noncontrolling interests before income tax expense											(563	)		661
Income tax expense		262		272		485		683			114			135
Net Income Including Noncontrolling Interests		883		696		1,887		1,787
Net Income (Loss) Including Noncontrolling Interests											(677	)		526
Noncontrolling Interests		29		31		81		100			3			23
Net Income Attributable to Dominion Energy	$	854	$	665	$	1,806	$	1,687
Net Income (Loss) Attributable to Dominion Energy										$	(680	)	$	503
Earnings Per Common Share
Net income attributable to Dominion Energy - Basic	$	1.31	$	1.03	$	2.77	$	2.66
Net income attributable to Dominion Energy - Diluted		1.30		1.03		2.77		2.66
Dividends Declared Per Common Share	$	0.8350	$	0.7700	$	2.505	$	2.280
Net income (loss) attributable to Dominion Energy - Basic										$	(0.86	)	$	0.77
Net income (loss) attributable to Dominion Energy - Diluted											(0.86	)		0.77

(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 March 31,
	2018			2017			2018			2017			2019			2018
(millions)
Net income including noncontrolling interests	$	883		$	696		$	1,887		$	1,787
Net income (loss) including noncontrolling interests													$	(677	)	$	526
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		(27	)		11			51			82			(24	)		111
Changes in unrealized net gains (losses) on investment securities⁽²⁾		(6	)		48			(24	)		141			16			(13	)
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities⁽³⁾		30			(15	)		71			(56	)		(31	)		8
Net realized (gains) losses on investment securities⁽⁴⁾		3			(4	)		4			(36	)		—			1
Net pension and other postretirement benefit costs⁽⁵⁾		18			14			60			38			8			25
Changes in other comprehensive income from equity method investees⁽⁶⁾		—			—			1			2
Total other comprehensive income		18			54			163			171
Comprehensive income including noncontrolling interests		901			750			2,050			1,958
Total other comprehensive income (loss)														(31	)		132
Comprehensive income (loss) including noncontrolling interests														(708	)		658
Comprehensive income attributable to noncontrolling interests		29			31			82			100			3			24
Comprehensive income attributable to Dominion Energy	$	872		$	719		$	1,968		$	1,858
Comprehensive income (loss) attributable to Dominion Energy													$	(711	)	$	634

(1)	Net of $9$5 million and ~~$(5)~~$(37) million tax for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and net of $(17) million and $(49) million tax for the nine months ended September 30, 2018 and 2017,~~ respectively.

(2)	Net of $1$(6) million and ~~$(27)~~$4 million tax for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and net of $7 million and $(80) million tax for the nine months ended September 30, 2018 and 2017,~~ respectively.

(3)	Net of ~~$(10)~~$10 million and ~~$10~~$(3) million tax for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and net of $(24) million and $35 million tax for the nine months ended September 30, 2018 and 2017,~~ respectively.

(4)	Net of $— million and $2 million tax for the three months ended September 30, 2018 and 2017, respectively, and net of $(1) million and $20 million tax for the nine months ended September 30, 2018 and 2017, respectively.

~~(5)~~

Net of $(7) million tax for both the three months ended September 30, 2018 and 2017, and net of $(15) million and $(25) million tax for the nine months ended September 30, 2018 and 2017, respectively.

~~(6)~~

Net of $— million tax for both the three months ended ~~September 30, 2018~~March 31, 2019 and ~~2017,~~2018.

(5)	Net of $(14) million and ~~net of~~ $(1) million tax for ~~both~~ the ~~nine~~three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017.~~respectively.

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

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2018			December 31, 2017⁽¹⁾			March 31, 2019			December 31, 2018⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	310		$	120		$	422		$	268
Customer receivables (less allowance for doubtful accounts of $17 at both dates)		1,539			1,660
Other receivables (less allowance for doubtful accounts of $2 at both dates)⁽²⁾		132			126
Customer receivables (less allowance for doubtful accounts of $22 and $14)								2,236			1,749
Other receivables (less allowance for doubtful accounts of $4 at both dates)⁽²⁾								203			331
Inventories		1,455			1,477			1,657			1,418
Regulatory assets		540			294			725			496
Assets held for sale		1,029			—
Other		697			657			732			899
Total current assets		5,702			4,334			5,975			5,161
Investments
Nuclear decommissioning trust funds		5,424			5,093			5,580			4,938
Investment in equity method affiliates		1,858			1,544			1,433			1,278
Other		345			327			357			344
Total investments		7,627			6,964			7,370			6,560
Property, Plant and Equipment
Property, plant and equipment		76,190			74,823			93,485			76,578
Accumulated depreciation, depletion and amortization		(22,005	)		(21,065	)		(26,918	)		(22,018	)
Total property, plant and equipment, net		54,185			53,758			66,567			54,560
Deferred Charges and Other Assets
Goodwill		6,410			6,405			8,960			6,410
Intangible assets, net								887			670
Regulatory assets		2,316			2,480			7,575			2,676
Operating lease assets								486			—
Other		2,842			2,644			2,234			1,877
Total deferred charges and other assets		11,568			11,529			20,142			11,633
Total assets	$	79,082		$	76,585		$	100,054		$	77,914

(1)	Dominion Energy’s Consolidated Balance Sheet at December 31, ~~2017~~2018 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, 2018			December 31, 2017⁽¹⁾			March 31, 2019			December 31, 2018⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	3,101		$	3,078		$	3,080		$	3,624
Credit facility borrowings								—			73
Short-term debt		2,935			3,298			2,412			334
Accounts payable		587			875			920			914
Other⁽²⁾⁽³⁾		2,589			2,385
Accrued interest, payroll and taxes								957			836
Regulatory liabilities								612			356
Other⁽²⁾								1,795			1,510
Total current liabilities		9,212			9,636			9,776			7,647
Long-Term Debt
Long-term debt		27,300			25,588			32,043			26,328
Junior subordinated notes		3,431			3,981			3,431			3,430
Remarketable subordinated notes		1,384			1,379			1,387			1,386
Credit facility borrowings		73			—
Total long-term debt		32,188			30,948			36,861			31,144
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		5,079			4,523			6,108			5,116
Regulatory liabilities		7,146			6,916			10,799			6,840
Other⁽²⁾		5,031			5,192
Asset retirement obligations								4,985			2,250
Operating lease liabilities								418			—
Other								3,508			2,869
Total deferred credits and other liabilities		17,256			16,631			25,818			17,075
Total liabilities		58,656			57,215			72,455			55,866
Commitments and Contingencies (see Note 16)
Commitments and Contingencies (see Note 17)
Equity
Common stock – no par⁽⁴⁾		10,862			9,865
Common stock – no par⁽³⁾								20,834			12,588
Retained earnings		9,128			7,936			7,806			9,219
Accumulated other comprehensive loss		(1,520	)		(659	)		(1,731	)		(1,700	)
Total common shareholders' equity		18,470			17,142			26,909			20,107
Noncontrolling interests		1,956			2,228			690			1,941
Total equity		20,426			19,370			27,599			22,048
Total liabilities and equity	$	79,082		$	76,585		$	100,054		$	77,914

(1)	Dominion Energy’s Consolidated Balance Sheet at December 31, ~~2017~~2018 has been derived from the audited Consolidated Balance Sheet at that date.

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

(3)	~~See Note 11 for amounts classified as held for sale.~~

~~(4)~~

1 billion shares authorized; ~~655~~802 million shares and ~~645~~681 million shares outstanding at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

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

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

	Common Stock					Dominion Energy Shareholders						Total Common									Common Stock					Dominion Energy Shareholders						Total Common
	Shares		Amount			Retained Earnings			AOCI			Shareholders' Equity			Noncontrolling Interests			Total Equity			Shares		Amount			Retained Earnings			AOCI			Shareholders' Equity			Noncontrolling Interests			Total Equity
(millions)
December 31, 2016		628	$	8,550		$	6,854		$	(799	)	$	14,605		$	2,235		$	16,840
Net income including noncontrolling interests							1,687						1,687			100			1,787
Contributions from NRG to Four Brothers and Three Cedars													—			9			9
Issuance of common stock		16		1,232									1,232						1,232
Stock awards (net of change in unearned compensation)				17									17						17
Dividends and distributions							(1,435	)					(1,435	)		(123	)		(1,558	)
Other comprehensive income, net of tax										171			171						171
Other				(10	)		13						3			1			4
September 30, 2017		644	$	9,789		$	7,119		$	(628	)	$	16,280		$	2,222		$	18,502

December 31, 2017		645	$	9,865		$	7,936		$	(659	)	$	17,142		$	2,228		$	19,370			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					(127	)		1,029			(1,023	)		(121	)		127			6
Net income including noncontrolling interests							1,806						1,806			81			1,887								503						503			23			526
Issuance of common stock		10		737									737						737			8		580									580						580
Sale of Dominion Energy Midstream common units - net of offering costs													—			4			4														—			4			4
Remeasurement of noncontrolling interest in Dominion Energy Midstream				375									375			(375	)		—
Stock awards (net of change in unearned compensation)				17									17						17					3									3						3
Dividends and distributions							(1,635	)					(1,635	)		(110	)		(1,745	)
Dividends ($0.835 per common share) and distributions																											(544	)					(544	)		(31	)		(575	)
Other comprehensive income, net of tax										162			162			1			163											131			131			1			132
Other				(5	)		(8	)					(13	)					(13	)				(5	)								(5	)		1			(4	)
September 30, 2018		655	$	10,862		$	9,128		$	(1,520	)	$	18,470		$	1,956		$	20,426
March 31, 2018																						653	$	10,316		$	8,924		$	(1,551	)	$	17,689		$	2,353		$	20,042

December 31, 2018																						681	$	12,588		$	9,219		$	(1,700	)	$	20,107		$	1,941		$	22,048
Net income (loss) including noncontrolling interests																											(680	)					(680	)		3			(677	)
Issuance of common stock																						3		247									247						247
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	)
Dividends ($0.9175 per common share) and distributions																											(733	)					(733	)		(33	)		(766	)
Other comprehensive loss, net of tax																														(31	)		(31	)					(31	)
March 31, 2019																						802	$	20,834		$	7,806		$	(1,731	)	$	26,909		$	690		$	27,599

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,	2018			2017
Three Months Ended March 31,							2019			2018
(millions)
Operating Activities
Net income including noncontrolling interests	$	1,887		$	1,787
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Net income (loss) including noncontrolling interests							$	(677	)	$	526
Adjustments to reconcile net income (loss) including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)		1,706			1,649			734			572
Deferred income taxes and investment tax credits		486			652			106			131
Proceeds from assignment of tower rental portfolio		—			91
Contribution to pension plan		—			(75	)
Gains on sales of assets and equity method investments		(196	)		(61	)
Provision for rate credits to electric utility customers		77			—
Charge associated with future ash pond and landfill closure costs		81			—
Charge associated with FERC-regulated plant disallowance		129			—
Net gains on nuclear decommissioning trusts funds and other investments		(208	)		(101	)
Provision for refunds and rate credits to electric utility customers								988			215
Impairment of assets and other charges								835			—
Net (gains) losses on nuclear decommissioning trust funds and other investments								(271	)		25
Revision to future ash pond and landfill closure costs								(113	)		—
Other adjustments		10			14			(11	)		(56	)
Changes in:
Accounts receivable		129			247			153			47
Inventories		(37	)		(34	)		53			104
Deferred fuel and purchased gas costs, net		(226	)		(81	)		27			(264	)
Prepayments		(81	)		34			89			(3	)
Accounts payable		(167	)		(158	)		(284	)		(57	)
Accrued interest, payroll and taxes		(14	)		61			(329	)		(103	)
Customer deposits								(35	)		101
Margin deposit assets and liabilities		(5	)		51			93			(33	)
Net realized and unrealized changes related to derivative activities		101			18
Pension and other postretirement benefits		(79	)		(132	)
Other operating assets and liabilities		118			(290	)		(187	)		27
Net cash provided by operating activities		3,711			3,672			1,171			1,232
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(3,111	)		(4,122	)		(1,002	)		(1,103	)
Cash and restricted cash acquired in the SCANA Combination								389			—
Acquisition of solar development projects		(108	)		(343	)		(29	)		(7	)
Proceeds from sales of securities		1,301			1,496			506			419
Purchases of securities		(1,364	)		(1,555	)		(494	)		(453	)
Proceeds from assignments of shale development rights		109			5
Proceeds from sale of certain merchant generation assets		91			—
Proceeds from sales of assets and equity method investments								154			—
Contributions to equity method affiliates		(282	)		(343	)		(69	)		(87	)
Other		(5	)		(6	)		(7	)		48
Net cash used in investing activities		(3,369	)		(4,868	)		(552	)		(1,183	)
Financing Activities
Repayment of short-term debt, net		(363	)		(95	)
Issuance (repayment) of short-term debt, net								1,905			(585	)
Issuance of short-term notes		1,450			—			—			950
Repayment of short-term notes		(1,450	)		(250	)
Repayment of credit facility borrowings								(113	)		—
Issuance of long-term debt		4,400			3,480			600			950
Repayment of long-term debt		(3,154	)		(1,529	)
Credit facility borrowings		73			—
Repayment of long-term debt, including redemption premiums								(2,217	)		(1,180	)
Issuance of common stock		737			1,233			247			581
Common dividend payments		(1,635	)		(1,435	)		(733	)		(544	)
Other		(198	)		(229	)		(72	)		(72	)
Net cash provided by (used in) financing activities		(140	)		1,175			(383	)		100
Increase (decrease) in cash, restricted cash and equivalents		202			(21	)
Increase in cash, restricted cash and equivalents								236			149
Cash, restricted cash and equivalents at beginning of period		185			322			391			185
Cash, restricted cash and equivalents at end of period	$	387		$	301		$	627		$	334
Supplemental Cash Flow Information
Significant noncash investing and financing activities:⁽¹⁾⁽²⁾
Significant noncash investing and financing activities:^(1)(2)(3)
Accrued capital expenditures	$	197		$	355		$	201		$	175

(1)	See Note 102 for noncash investing and financing activities related to ~~equity method investments.~~the adoption of a new accounting standard for leasing arrangements.

(2)	See Note 153 for noncash investing and financing activities related to the ~~remeasurement~~SCANA Combination.

(3)	See Note 16 for noncash financing activities related to the acquisition of ~~Dominion Energy’s noncontrolling~~the public interest in Dominion Energy Midstream.

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 March 31,
	2018		2017		2018		2017			2019		2018
(millions)
Operating Revenue⁽¹⁾	$	2,232	$	2,154	$	5,809	$	5,732		$	1,965	$	1,748
Operating Expenses
Electric fuel and other energy-related purchases⁽¹⁾		648		549		1,747		1,414			596		591
Purchased (excess) electric capacity		50		21		87		(8	)
Purchased electric capacity											33		14
Other operations and maintenance:
Affiliated suppliers		72		76		229		229			86		83
Other		332		297		1,013		897			193		316
Depreciation and amortization		295		288		839		854			304		297
Other taxes		79		76		241		233			85		83
Impairment of assets and other charges											546		—
Total operating expenses		1,476		1,307		4,156		3,619			1,843		1,384
Income from operations		756		847		1,653		2,113			122		364
Other income		25		13		49		57			37		3
Interest and related charges⁽¹⁾		130		128		388		373			135		132
Income before income tax expense		651		732		1,314		1,797			24		235
Income tax expense		131		273		271		664			4		51
Net Income	$	520	$	459	$	1,043	$	1,133		$	20	$	184

(1)	See Note 1819 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 March 31,
	2018		2017			2018			2017			2019			2018
(millions)
Net income	$	520	$	459		$	1,043		$	1,133		$	20		$	184
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		3		(2	)		10			(5	)		(7	)		5
Changes in unrealized net gains (losses) on nuclear decommissioning trust funds⁽²⁾		—		6			(2	)		17			2			—
Amounts reclassified to net income:
Net derivative (gains) losses on derivative-hedging activities⁽³⁾		—		—			—			1
Net realized (gains) losses on nuclear decommissioning trust funds⁽⁴⁾		—		—			—			(4	)
Total other comprehensive income		3		4			8			9
Total other comprehensive income (loss)													(5	)		5
Comprehensive income	$	523	$	463		$	1,051		$	1,142		$	15		$	189

(1)	Net of $2 million and $(2) million tax for the three months ended March 31, 2019 and 2018, respectively.

(2)	Net of $(1) million and $1 million tax for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and net of $(3) million and $3 million tax for the nine months ended September 30, 2018 and 2017, respectively.~~

~~(2)~~

Net of $— million and $(4) million tax for the three months ended September 30, 2018 and 2017, respectively, and net of $1 million and $(11) million tax for the nine months ended September 30, 2018 and 2017, respectively.

~~(3)~~

~~Net of $— million tax for both the three and nine months ended September 30, 2018 and 2017.~~

~~(4)~~

~~Net of $— million tax for both the three months ended September 30, 2018 and 2017, and net of $— million and $2 million tax for the nine months ended September 30, 2018 and 2017,~~ 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, 2018			December 31, 2017⁽¹⁾			March 31, 2019			December 31, 2018⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	22		$	14		$	14		$	29
Customer receivables (less allowance for doubtful accounts of $10 at both dates)		1,077			951
Other receivables (less allowance for doubtful accounts of $1 at both dates)		51			64
Customer receivables (less allowance for doubtful accounts of $9 at both dates)								935			999
Other receivables (less allowance for doubtful accounts of $3 at both dates)								75			76
Affiliated receivables		2			3			59			101
Inventories (average cost method)		810			850			836			837
Regulatory assets		479			205
Other⁽²⁾		134			137			454			529
Total current assets		2,575			2,224			2,373			2,571
Investments
Nuclear decommissioning trust funds		2,573			2,399			2,591			2,369
Other		3			3			3			3
Total investments		2,576			2,402			2,594			2,372
Property, Plant and Equipment
Property, plant and equipment		43,935			42,329			45,107			44,524
Accumulated depreciation and amortization		(13,889	)		(13,277	)		(13,614	)		(14,003	)
Total property, plant and equipment, net		30,046			29,052			31,493			30,521
Deferred Charges and Other Assets
Regulatory assets		636			810			1,719			737
Operating lease assets								202			—
Other⁽²⁾		702			651			893			679
Total deferred charges and other assets		1,338			1,461			2,814			1,416
Total assets	$	36,535		$	35,139		$	39,274		$	36,880

(1)	Virginia Power’s Consolidated Balance Sheet at December 31, ~~2017~~2018 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 1819 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, 2018			December 31, 2017⁽¹⁾		March 31, 2019			December 31, 2018⁽¹⁾
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	350		$	850	$	392		$	350
Short-term debt		934			542		595			314
Accounts payable		269			361		255			339
Payables to affiliates		116			125		104			209
Affiliated current borrowings		15			33		24			224
Accrued interest, payroll and taxes		306			256
Asset retirement obligations		149			216
Regulatory liabilities							281			299
Other⁽²⁾		849			537		1,105			1,080
Total current liabilities		2,988			2,920		2,756			2,815
Long-Term Debt		10,742			10,496		11,288			11,321
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,948			2,728		2,985			3,017
Asset retirement obligations		1,314			1,149		3,375			1,200
Regulatory liabilities		4,890			4,760		4,808			4,647
Operating lease liabilities							169			—
Other⁽²⁾		736			862		949			833
Total deferred credits and other liabilities		9,888			9,499		12,286			9,697
Total liabilities		23,618			22,915		26,330			23,833
Commitments and Contingencies (see Note 16)
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		6,072			5,311		6,110			6,208
Accumulated other comprehensive income (loss)		(6	)		62
Accumulated other comprehensive loss							(17	)		(12	)
Total common shareholder’s equity		12,917			12,224		12,944			13,047
Total liabilities and shareholder’s equity	$	36,535		$	35,139	$	39,274		$	36,880

(1)	Virginia Power’s Consolidated Balance Sheet at December 31, ~~2017~~2018 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 1819 for amounts attributable to affiliates.

(3)	500,000 shares authorized; 274,723 shares outstanding at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017.~~2018.

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED ~~STATEMENT~~STATEMENTS OF COMMON SHAREHOLDER’S EQUITY

(Unaudited)

	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			275	$	5,738	$	1,113	$	5,311		$	62		$	12,224
Cumulative-effect of changes in accounting principles								79			(76	)		3									79			(76	)		3
Net income								1,043						1,043									184						184
Dividends								(361	)					(361	)								(154	)					(154	)
Other comprehensive income, net of tax											8			8												5			5
September 30, 2018		275	$	5,738	$	1,113	$	6,072		$	(6	)	$	12,917
March 31, 2018																	275	$	5,738	$	1,113	$	5,420		$	(9	)	$	12,262

December 31, 2018																	275	$	5,738	$	1,113	$	6,208		$	(12	)	$	13,047
Net income																							20						20
Dividends																							(118	)					(118	)
Other comprehensive loss, net of tax																										(5	)		(5	)
March 31, 2019																	275	$	5,738	$	1,113	$	6,110		$	(17	)	$	12,944

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,	2018			2017
Three Months Ended March 31,							2019			2018
(millions)
Operating Activities
Net income	$	1,043		$	1,133		$	20		$	184
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		974			999			346			343
Deferred income taxes and investment tax credits		175			262			(49	)		83
Proceeds from assignment of tower rental portfolio		—			91
Charges 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								546			—
Provision for rate credits to customers		77			—			—			215
Other adjustments		(48	)		(28	)		(39	)		(1	)
Changes in:
Accounts receivable		(113	)		32			62			78
Affiliated receivables and payables		(8	)		159			(63	)		(59	)
Inventories		40			1			(19	)		54
Prepayments		(1	)		(3	)		(2	)		(11	)
Deferred fuel expenses, net		(273	)		(48	)		24			(328	)
Accounts payable		(28	)		(33	)		(33	)		3
Accrued interest, payroll and taxes		50			67			15			(5	)
Net realized and unrealized changes related to derivative activities		69			—			14			49
Asset retirement obligations		(29	)		(63	)
Other operating assets and liabilities		197			(99	)		(66	)		(26	)
Net cash provided by operating activities		2,206			2,470			643			579
Investing Activities
Plant construction and other property additions		(1,696	)		(1,901	)		(563	)		(570	)
Purchases of nuclear fuel		(82	)		(133	)		(11	)		(46	)
Acquisition of solar development projects		(98	)		(16	)		(27	)		—
Proceeds from sales of securities		651			654			253			218
Purchases of securities		(681	)		(681	)		(269	)		(235	)
Other		(47	)		(29	)		(3	)		(6	)
Net cash used in investing activities		(1,953	)		(2,106	)		(620	)		(639	)
Financing Activities
Issuance of short-term debt, net		392			255
Issuance (repayment) of short-term debt, net								281			(116	)
Repayment of affiliated current borrowings, net		(18	)		(226	)		(200	)		(22	)
Issuance of long-term debt		700			1,500			—			700
Repayment of long-term debt		(951	)		(679	)		—			(350	)
Common dividend payments to parent		(361	)		(1,199	)		(118	)		(154	)
Other		(7	)		(10	)		(1	)		(6	)
Net cash used in financing activities		(245	)		(359	)
Increase in cash, restricted cash and equivalents		8			5
Net cash provided by (used in) financing activities								(38	)		52
Decrease in cash, restricted cash and equivalents								(15	)		(8	)
Cash, restricted cash and equivalents at beginning of period		24			11			38			24
Cash, restricted cash and equivalents at end of period	$	32		$	16		$	23		$	16
Supplemental Cash Flow Information
Significant noncash investing activities:
Significant noncash investing activities:⁽¹⁾
Accrued capital expenditures	$	96		$	158		$	117		$	104

(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 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 March 31,
	2018			2017		2018		2017		2019		2018
(millions)
Operating Revenue⁽¹⁾	$	423		$	401	$	1,408	$	1,313	$	511	$	526
Operating Expenses
Purchased (excess) gas⁽¹⁾		(7	)		19		22		100
Purchased gas⁽¹⁾											40		29
Other energy-related purchases		26			4		88		11		26		31
Other operations and maintenance:
Affiliated suppliers		21			20		70		65		30		23
Other		95			74		513		375		153		167
Depreciation and amortization		61			57		173		167		62		59
Other taxes		45			42		152		139		64		60
Gains on sales of assets											—		(44	)
Total operating expenses		241			216		1,018		857		375		325
Income from operations		182			185		390		456		136		201
Earnings from equity method investee		4			4		18		15		6		9
Other income		34			27		99		79		34		33
Interest and related charges⁽¹⁾		28			25		79		72		26		25
Income from operations before income taxes		192			191		428		478		150		218
Income tax expense		56			74		111		176		34		52
Net Income	$	136		$	117	$	317	$	302	$	116	$	166

(1)	See Note 1819 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,						Three Months Ended March 31,
	2018		2017			2018			2017			2019			2018
(millions)
Net income	$	136	$	117		$	317		$	302		$	116		$	166
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		3		1			(4	)		3			(27	)		13
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities⁽²⁾		5		(4	)		16			(5	)		4			(3	)
Net pension and other postretirement benefit costs⁽³⁾		2		1			4			3			1			1
Total other comprehensive income (loss)		10		(2	)		16			1			(22	)		11
Comprehensive income	$	146	$	115		$	333		$	303		$	94		$	177

(1)	Net of $9 million and $(4) million tax for the three months ended March 31, 2019 and 2018, respectively.

(2)	Net of $(1) million and $1 million tax for the three months ended March 31, 2019 and 2018, respectively.

(3)	Net of $(1) million tax for both the three months ended ~~September 30, 2018~~March 31, 2019 and ~~2017, and net of $2 million and $(2) million tax for the nine months ended September 30, 2018 and 2017, respectively.~~

~~(2)~~

Net of $(2) million and $3 million tax for the three months ended September 30, 2018 and 2017, respectively, and net of $(6) million and $3 million tax for the nine months ended September 30, 2018 and 2017, respectively.

~~(3)~~

~~Net of $— million~~ and $(1) million tax for the three months ended September 30, 2018 and 2017, respectively, and net of $(1) million and $(2) million tax for the nine months ended September 30, 2018 and 2017, respectively.2018.

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	September 30, 2018			December 31, 2017⁽¹⁾			March 31, 2019			December 31, 2018⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	4		$	4		$	4		$	10
Customer receivables (less allowance for doubtful accounts of less than $1 and $1)⁽²⁾		196			297
Other receivables (less allowance for doubtful accounts of $1 at both dates)⁽²⁾		18			15
Customer receivables (less allowance for doubtful accounts of less than $1 at both dates)⁽²⁾								354			309
Other receivables (less allowance for doubtful accounts of $2 at both dates)⁽²⁾								17			17
Affiliated receivables		6			10			7			10
Inventories		89			64			82			65
Gas imbalances⁽²⁾		59			46			80			162
Prepayments		66			112
Other		47			52			126			174
Total current assets		485			600			670			747
Investments		95			97			92			93
Property, Plant and Equipment
Property, plant and equipment		11,577			11,173			11,395			11,238
Accumulated depreciation and amortization		(3,159	)		(3,018	)		(3,004	)		(2,971	)
Total property, plant and equipment, net		8,418			8,155			8,391			8,267
Deferred Charges and Other Assets
Pension and other postretirement benefit assets⁽²⁾		1,946			1,828			1,815			1,775
Operating lease assets								63			—
Other⁽²⁾		1,311			1,260			1,483			1,469
Total deferred charges and other assets		3,257			3,088			3,361			3,244
Total assets	$	12,255		$	11,940		$	12,514		$	12,351

(1)	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, ~~2017~~2018 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 1819 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, 2018			December 31, 2017⁽¹⁾			March 31, 2019			December 31, 2018⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year							$	451		$	449
Short-term debt	$	141		$	629			280			10
Accounts payable		81			193			161			196
Payables to affiliates		33			62			56			65
Affiliated current borrowings		24			18			47			218
Other⁽²⁾		434			439			401			463
Total current liabilities		713			1,341			1,396			1,401
Long-Term Debt		4,061			3,570			3,607			3,609
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		1,513			1,454			1,479			1,465
Regulatory liabilities		1,309			1,227			1,291			1,285
Operating lease liabilities								49			—
Other		185			185			201			194
Total deferred credits and other liabilities		3,007			2,866			3,020			2,944
Total liabilities		7,781			7,777			8,023			7,954
Commitments and Contingencies (see Note 16)
Commitments and Contingencies (see Note 17)
Equity
Membership interests		4,582			4,261			4,682			4,566
Accumulated other comprehensive loss		(108	)		(98	)		(191	)		(169	)
Total equity		4,474			4,163			4,491			4,397
Total liabilities and equity	$	12,255		$	11,940		$	12,514		$	12,351

(1)	Dominion Energy Gas’ Consolidated Balance Sheet at December 31, ~~2017~~2018 has been derived from the audited Consolidated Balance Sheet at that date.

(2)	See Note 1819 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 ~~STATEMENT~~STATEMENTS OF EQUITY

(Unaudited)

	Membership Interests			AOCI			Total			Membership Interests			AOCI			Total
(millions)
December 31, 2017	$	4,261		$	(98	)	$	4,163		$	4,261		$	(98	)	$	4,163
Cumulative-effect of changes in accounting principles		29			(26	)		3			29			(26	)		3
Net income		317						317			166						166
Distributions		(25	)					(25	)		(13	)					(13	)
Other comprehensive income, net of tax					16			16						11			11
September 30, 2018	$	4,582		$	(108	)	$	4,474
March 31, 2018										$	4,443		$	(113	)	$	4,330

December 31, 2018										$	4,566		$	(169	)	$	4,397
Net income											116						116
Other comprehensive loss, net of tax														(22	)		(22	)
March 31, 2019										$	4,682		$	(191	)	$	4,491

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Nine Months Ended September 30,	2018			2017
Three Months Ended March 31,							2019			2018
(millions)
Operating Activities
Net income	$	317		$	302		$	116		$	166
Adjustments to reconcile net income to net cash provided by operating activities:
Gains on sales of assets		(109	)		(61	)		—			(44	)
Charge associated with FERC-regulated plant disallowance		129			—
Depreciation and amortization		173			167			62			59
Deferred income taxes and investment tax credits		86			176			17			14
Other adjustments		5			(9	)		(3	)		(4	)
Changes in:
Accounts receivable		98			88			(45	)		(28	)
Affiliated receivables and payables		(25	)		(11	)		(6	)		28
Inventories		(25	)		(20	)		(17	)		(7	)
Deferred purchased gas costs, net		8			11			9			8
Prepayments		46			39			19			16
Accounts payable		(110	)		(68	)		(24	)		(39	)
Accrued interest, payroll and taxes		(46	)		(28	)		(33	)		(30	)
Pension and other postretirement benefits		(108	)		(98	)		(36	)		(36	)
Other operating assets and liabilities		23			(13	)		(31	)		(1	)
Net cash provided by operating activities		462			475			28			102
Investing Activities
Plant construction and other property additions		(550	)		(535	)		(138	)		(138	)
Proceeds from assignments of shale development rights		109			5			—			44
Other		(14	)		(7	)		(3	)		(5	)
Net cash used in investing activities		(455	)		(537	)		(141	)		(99	)
Financing Activities
Issuance (repayment) of short-term debt, net		(488	)		160			270			(15	)
Issuance of long-term debt		500			—
Issuance (repayment) of affiliated current borrowings, net		6			(84	)		(171	)		23
Distribution payments to parent		(25	)		(15	)		—			(13	)
Other		(4	)		—			—			1
Net cash provided by (used in) financing activities		(11	)		61			99			(4	)
Decrease in cash, restricted cash and equivalents		(4	)		(1	)		(14	)		(1	)
Cash, restricted cash and equivalents at beginning of period		30			43			34			30
Cash, restricted cash and equivalents at end of period	$	26		$	42		$	20		$	29
Supplemental Cash Flow Information
Significant noncash investing activities:
Significant noncash investing activities:⁽¹⁾
Accrued capital expenditures	$	43		$	54		$	16		$	29

(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. 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 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 primarily in the eastern and Rocky Mountain regions of the U.S. The SCANA Combination was completed in January 2019. See Note 3 for a description of operations acquired in the SCANA Combination.

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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018.

In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of ~~September 30, 2018,~~March 31, 2019 and their results of operations, ~~for the three~~changes in equity and ~~nine months ended September 30, 2018 and 2017, their~~ cash flows for the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 and 2017, Dominion Energy’s changes in equity for the nine months ended September 30, 2018 and 2017 and Virginia Power and Dominion Energy Gas’ changes in equity for the nine months ended September 30, 2018. 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 ~~September 30,~~December 31, 2018, Dominion Energy ~~owns~~owned the general partner, 60.9% of the common units and 37.5% of the convertible preferred interests in Dominion Energy ~~Midstream. The~~Midstream, with the public’s ownership interest ~~in Dominion Energy Midstream is~~ 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 ~~September 30, 2018,~~March 31, 2019, Dominion Energy owns 50% of the units in and consolidates Four Brothers and Three Cedars. ~~In August 2018, NRG’s ownership interest in Four Brothers and Three Cedars was transferred to GIP.~~ 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, is 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 projects upon the occurrence of certain events, none of which had occurred at ~~September 30, 2018~~March 31, 2019 nor are expected to occur in the remainder of ~~2018.~~2019.

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’ ~~2017~~2018 Consolidated Financial Statements and Notes have been reclassified as a result of the adoption of revised accounting guidance pertaining to certain net periodic pension and other postretirement benefit costs, restricted cash and equivalents and certain distributions from equity method investees. In addition, certain other amounts have been reclassified to conform to the ~~2018~~2019 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. The effects of the adoption of new accounting standards on the Consolidated Financial Statements are described below. With the exception of the property, plant and equipment item described below, thereThere have been no ~~other~~ 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6, 2018.~~2018, with the exception of the items described below.

~~Operating Revenue~~

Operating revenue is recorded on the basis of services rendered, commodities delivered or contracts settled and includes amounts yet to be billed to customers. Dominion Energy and Virginia Power collect sales, consumption and consumer utility taxes and Dominion Energy Gas collects sales taxes; however, these amounts are excluded from revenue. Dominion Energy’s customer receivables include accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to utility customers. Virginia Power’s customer receivables include accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to customers. Dominion Energy Gas’ customer receivables include accrued unbilled revenue based on estimated amounts of natural gas delivered and services provided but not yet billed to customers.

The primary types of sales and service activities reported as operating revenue for Dominion Energy, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows:

~~Revenue from Contracts with Customers~~

~~Regulated electric sales~~ ~~consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;~~

~~Nonregulated electric sales~~ ~~consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated hedging activity;~~

~~Regulated gas sales~~ ~~consist primarily of state-regulated natural gas sales and related distribution services;~~

~~Nonregulated gas sales~~ ~~consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties and associated hedging activity;~~

~~Regulated gas transportation and storage sales~~ consist of FERC-regulated sales of transmission and storage services and state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services;

~~Nonregulated gas transportation and storage sales~~ ~~consist primarily of LNG terminalling services;~~

~~Other regulated revenue~~ ~~consists primarily of miscellaneous service revenue from electric and gas distribution operations and sales of excess electric capacity and other commodities; and~~

~~Other nonregulated revenue~~ consists primarily of NGL gathering and processing, sales of NGL production and condensate, extracted products and associated hedging activity. Other nonregulated revenue also includes services performed for Atlantic Coast Pipeline, sales of energy-related products and services from Dominion Energy’s retail energy marketing operations, service concession arrangements and gas processing and handling revenue.

~~Other Revenue~~

~~Other revenue~~ ~~consists primarily of alternative revenue programs, gains and losses from derivative instruments not subject to hedge accounting and lease revenues.~~

The primary types of sales and service activities reported as operating revenue for Dominion Energy, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows:

~~Regulated electric sales~~ ~~consisted primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;~~

~~Nonregulated electric sales~~ ~~consisted primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity;~~

~~Regulated gas sales~~ ~~consisted primarily of state- and FERC-regulated natural gas sales and related distribution services and associated derivative activity;~~

~~Nonregulated gas sales~~ consisted primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity;

~~Gas transportation and storage sales~~ consisted primarily of FERC-regulated sales of transmission and storage services. Also included were state-regulated gas distribution charges to retail distribution service customers opting for alternate suppliers and sales of gathering services; and

~~Other revenue~~ consisted primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also included miscellaneous service revenue from electric and gas distribution operations, sales of energy-related products and services from Dominion Energy’s retail energy marketing operations and gas processing and handling revenue.

The primary types of sales and service activities reported as operating revenue for Virginia Power, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows:

~~Revenue from Contracts with Customers~~

~~Regulated electric sales~~ ~~consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;~~

~~Other regulated revenue~~ ~~consists primarily of sales of excess capacity and other commodities and miscellaneous service revenue from electric distribution operations; and~~

~~Other nonregulated revenue~~ consists primarily of sales to non-jurisdictional customers from certain solar facilities, revenue from renting space on certain electric transmission poles and distribution towers and service concession arrangements.

~~Other Revenue~~

~~Other revenue~~ ~~consists primarily of alternative revenue programs, gains and losses from derivative instruments not subject to hedge accounting and lease revenues.~~

The primary types of sales and service activities reported as operating revenue for Virginia Power, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows:

~~Regulated electric sales~~ ~~consisted primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services; and~~

~~Other revenue~~ ~~consisted primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities.~~

The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, subsequent to the adoption of revised guidance for revenue recognition from contracts with customers, are as follows:

~~Revenue from Contracts with Customers~~

~~Regulated gas sales~~ ~~consist primarily of state-regulated natural gas sales and related distribution services;~~

~~Nonregulated gas sales~~ ~~consist primarily of sales of gas purchased from third parties and royalty revenues;~~

~~NGL revenue~~ ~~consists primarily of NGL gathering and processing, sales of NGL production and condensate, extracted products and associated hedging activity;~~

~~Management service revenue~~ ~~consists primarily of services performed for Atlantic Coast Pipeline;~~

~~Other regulated revenue~~ ~~consists primarily of miscellaneous regulated revenues; and~~

~~Other nonregulated revenue~~ ~~consists primarily of miscellaneous service revenue.~~

~~Other Revenue~~

~~Other revenue~~ ~~consists primarily of gains and losses from derivative instruments not subject to hedge accounting.~~

The primary types of sales and service activities reported as operating revenue for Dominion Energy Gas, prior to the adoption of revised guidance for revenue recognition from contracts with customers, were as follows:

~~Regulated gas sales~~ ~~consisted primarily of state- and FERC-regulated natural gas sales and related distribution services;~~

~~Nonregulated gas sales~~ consisted primarily of sales of natural gas production at market-based rates and contracted fixed prices and sales of gas purchased from third parties. Revenue from sales of gas production was recognized based on actual volumes of gas sold to purchasers and was reported net of royalties;

~~NGL revenue~~ ~~consisted primarily of sales of NGL production and condensate, extracted products and associated derivative activity; and~~

~~Other revenue~~ ~~consisted primarily of miscellaneous service revenue, gas processing and handling revenue.~~

Alternative revenue programs compensate Dominion Energy and Virginia Power for certain projects and initiatives. Revenues arising from these programs are presented separately from revenue arising from contracts with customers in the categories above. Currently, Dominion Energy and Virginia Power account for the equity return for under-recovery of certain riders under the alternative revenue program guidance.

Revenues from electric and gas sales are recognized over time, as the customers of the Companies consume gas and electricity as it is delivered. Transportation and storage contracts are primarily stand-ready service contracts that include fixed reservation and variable usage fees. LNG terminalling services are also stand-ready service contracts, primarily consisting of fixed fees, offset by service credits associated with the start-up phase of the Liquefaction Project. Fixed fees are recognized ratably over the life of the contract as the stand-ready performance obligation is satisfied, while variable usage fees are recognized when Dominion Energy and Dominion Energy Gas have a right to consideration from a customer in an amount that corresponds directly with the value to the customer of the performance obligation completed to date. Sales of products, such as NGLs, typically transfer control and are recognized as revenue upon delivery of the product. The customer is able to direct the use of, and obtain substantially all of the benefits from, the product at the time the product is delivered. The contract with the customer states the final terms of the sale, including the description, quantity and price of each product or service purchased. Payment for most sales and services varies by contract type, but is typically due within a month of billing.

Dominion Energy and Dominion Energy Gas typically receive or retain NGLs and natural gas from customers when providing natural gas processing, transportation or storage services. The revised guidance for revenue from contracts with customers requires entities to include the fair value of the noncash consideration in the transaction price. Therefore, subsequent to the adoption of the revised guidance for revenue recognition from contracts with customers, Dominion Energy and Dominion Energy Gas record the fair value of NGLs received during natural gas processing as service revenue recognized over time, and continue to recognize revenue from the subsequent sale of the NGLs to customers upon delivery. Dominion Energy and Dominion Energy Gas typically retain natural gas under certain transportation service arrangements that are intended to facilitate performance of the service and allow for natural losses that occur. As the intent of the allowance is to enable fulfillment of the contract rather than to provide compensation for services, the fuel allowance is not included in revenue.

Cash, Restricted Cash and Equivalents

~~Restricted Cash and Equivalents~~

The Companies hold restricted cash and equivalent balances that primarily consist of amounts held for certain customer deposits, future debt payments on SBL Holdco and Dominion Solar Projects III, Inc.’s term loan agreements and a distribution reserve at Cove Point. Upon adoption of revised accounting guidance in January 2018, restricted cash and equivalents are included within the Companies’ Consolidated Statements of Cash Flows, with the change in balance no longer considered a separate investing activity. The guidance required retrospective application which resulted in an adjustment to Dominion Energy and Dominion Energy Gas’ other cash used in investing activities for the nine months ended September 30, 2017, which had been previously reported as $6 million and $16 million, respectively. There was no impact to Virginia Power for the nine months ended September 30, 2017. 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~~three months ended ~~September 30, 2018~~March 31, 2019 and ~~2017:~~2018:

	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, 2018		September 30, 2017		December 31, 2017		December 31, 2016		March 31, 2019		March 31, 2018		December 31, 2018		December 31, 2017
(millions)
Dominion Energy
Cash and cash equivalents	$	310	$	227	$	120	$	261	$	422	$	189	$	268	$	120
Restricted cash and equivalents⁽¹⁾		77		74		65		61		205		145		123		65
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	387	$	301	$	185	$	322	$	627	$	334	$	391	$	185
Virginia Power
Cash and cash equivalents	$	22	$	16	$	14	$	11	$	14	$	6	$	29	$	14
Restricted cash and equivalents⁽¹⁾		10		—		10		—		9		10		9		10
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	32	$	16	$	24	$	11	$	23	$	16	$	38	$	24
Dominion Energy Gas
Cash and cash equivalents	$	4	$	13	$	4	$	23	$	4	$	6	$	10	$	4
Restricted cash and equivalents ⁽¹⁾		22		29		26		20		16		23		24		26
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	26	$	42	$	30	$	43	$	20	$	29	$	34	$	30

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

~~Distributions from Equity Method Investees~~

Dominion Energy and Dominion Energy Gas each hold investments that are accounted for under the equity method of accounting. Effective January 2018, Dominion Energy and Dominion Energy Gas classify distributions from equity method investees as either cash flows from operating activities or cash flows from investing activities in the Consolidated Statements of Cash Flows according to the nature of the distribution. Distributions received are classified on the basis of the nature of the activity of the investee that generated the distribution as either a return on investment (classified as cash flows from operating activities) or a return of an investment (classified as cash flows from investing activities) when such information is available to Dominion Energy and Dominion Energy Gas. Previously, distributions were determined to be either a return on an investment or return of an investment based on a cumulative earnings approach whereby any distributions received in excess of earnings were considered to be a return of an investment. Dominion Energy and Dominion Energy Gas have applied this approach on a retrospective basis. As a result, distributions from equity method investees were reclassified within Dominion Energy’s Consolidated Statement of Cash Flows from other investing activities to other adjustments from operating activities, which were previously reported as ($95) million for the nine months ended September 30, 2017. There was no impact to Dominion Energy Gas for the nine months ended September 30, 2017.

Property, Plant and Equipment

In January 2019, Virginia Power committed to a plan to retire certain automated meter reading infrastructure associated with its electric operations before the ~~second quarter~~end of ~~2018,~~its useful life and replace such equipment with more current AMI technology. As a result, Virginia Power recorded ~~an adjustment for~~a charge of $160 million ($119 million after-tax), 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 ~~retroactive application of depreciation rates for regulated nuclear plants~~GTSA, subject to ~~comply with Virginia Commission requirements. This adjustment resulted~~review as discussed in ~~a decrease of $7 million ($5 million after-tax) and $53 million ($41 million after-tax) in depreciation expense~~Note 13 to the Consolidated Financial Statements in Virginia Power’s Annual Report on Form 10-K.

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 six 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 discussed in Note 17. As a result, Virginia Power recorded a charge of $369 million ($275 million after-tax), primarily included in impairment of assets and other charges in its Consolidated Statements of ~~Income for~~Income. This charge is considered a component of Virginia Power’s base rates deemed recovered under the ~~three~~GTSA, subject to review as discussed in Note 13 to the Consolidated Financial Statements in Virginia Power’s Annual Report on Form 10-K.

Leases

The Companies lease certain assets including vehicles, real estate, office equipment and ~~nine months ended September 30, 2018, respectively. This revision~~other operational assets under both operating and finance leases. For the Companies’ operating leases, rent expense is ~~expected to decrease annual depreciation~~recognized on a straight-line basis over the term of the lease agreement. Rent expense ~~by approximately $30 million ($23 million after-tax).~~

~~Investments~~

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

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~~operating leases, short-term leases and variable leases is primarily recorded in other ~~investments~~operations and maintenance expense in the Companies’ Consolidated Statements of Income. Rent expense associated with finance leases results 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 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. A right-of-use asset and corresponding lease liability for leases with original lease terms of one year or less are not included in the Consolidated Balance Sheets, ~~at fair~~unless such leases contain renewal options that the Companies are reasonably certain will be exercised. Additionally, certain 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 with variable payments based upon usage of, or revenues associated with, the leased assets.

The determination of the discount rate utilized has a significant impact on the calculation of the present value ~~with net realized and unrealized gains and losses~~of the lease liability included in ~~other income in~~ the ~~Consolidated Statements of Income.~~

~~Debt securities classified as available-for-sale securities~~ include all other debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in theCompanies’ Consolidated Balance Sheets. ~~Net realized~~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 in the lease is generally unable to be determined from a lessee perspective. As such, the Companies use internally-developed incremental borrowing rates as a discount rate in the calculation 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 ~~unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power’s nuclear decommissioning trusts~~an associated accounts receivable are recorded to a regulatory liability 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 other-than-temporary 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,~~when the ~~cost basis~~monthly output of the ~~security~~solar facility is ~~based~~determined. Depreciation on ~~the specific identification method.~~

Equity securities with readily determinable fair values include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans and securities held by Dominion Energy and Virginia Power in the nuclear decommissioning trusts. Dominion Energy and Virginia Power record all equity securities withthese solar facilities is computed on 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 investmentstraight-line basis over an estimated useful life 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 recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other equity securities, including those held in Dominion Energy’s merchant generation nuclear decommissioning trusts and rabbi trusts, net realized and unrealized gains and losses are included in other income in the Consolidated Statements of Income.30 years.

~~Equity Securities without Readily Determinable Fair Values~~

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

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

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

~~Other-Than-Temporary Impairment~~

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

~~Decommissioning Trust Investments – Special Considerations for Debt Securities~~

~~The recognition provisions of other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale or held-to-maturity.~~

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

New Accounting Standards

~~Revenue Recognition~~Leases

In May 2014, the FASB issued revised accounting guidance for revenue recognition from contracts with customers. The Companies adopted this revised accounting guidance for interim and annual reporting periods beginning January 1, 2018 using the modified retrospective method. Upon the adoption of the standard, Dominion Energy and Dominion Energy Gas recorded the cumulative-effect of a change in accounting principle of $3 million to retained earnings and membership interests, respectively, and to establish a contract asset related to changes in the timing of revenue recognition for three existing contracts with customers at DETI.

As a result of adopting this revised accounting guidance, Dominion Energy and Dominion Energy Gas record offsetting operating revenue and other energy-related purchases for non-cash consideration of performing processing and fractionation services related to NGLs. Such amounts at Dominion Energy were $24 million and $74 million, respectively, and at Dominion Energy Gas were $21 million and $71 million, respectively, recorded in the Consolidated Statements of Income for the three and nine months ended September 30, 2018. No such amounts were recorded during the three and nine months ended September 30, 2017. Dominion Energy and Dominion Energy Gas no longer record offsetting operating revenue and purchased gas for fuel retained to offset costs on certain transportation and storage arrangements. Such amounts at Dominion Energy were $20 million and $83 million, respectively, and at Dominion Energy Gas were $16 million and $64 million, respectively, recorded in the Consolidated Statements of Income for the three and nine months ended September 30, 2017.

~~Financial Instruments~~

~~In January~~February 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of ~~financial instruments.~~ 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, ~~2018 and the~~2019. The Companies adopted the standard using the modified retrospective method. Upon adoption of this guidance for equity securities held at January 1, 2018, Dominion Energy and Virginia Power recorded the cumulative-effect of a change in accounting principle to reclassify net unrealized gains from AOCI to retained earnings and to recognize equity securities previously categorized as

cost method investments at fair value (using NAV) in nuclear decommissioning trust funds in the Consolidated Balance Sheets and a cumulative-effect adjustment to retained earnings. Dominion Energy and Virginia Power reclassified approximately $1.1 billion ($734 million after-tax) and $119 million ($73 million after-tax), respectively, of net unrealized gains from AOCI to retained earnings. Dominion Energy and Virginia Power also recorded approximately $36 million ($22 million after-tax) in net unrealized gains on equity securities previously classified as cost method investments, of which $3 million was recorded to retained earnings and $33 million was recorded to regulatory liabilities for net unrealized gains subject to cost-based regulation. As a result of adopting this revised accounting guidance ~~Dominion Energy recorded unrealized gains on equity securities, net~~using a modified retrospective approach, which requires lessees and lessors to recognize and measure leases at the date of ~~regulatory deferrals, of $148 million ($116 million after-tax) and $146 million ($116 million after-tax) in other income in~~adoption. Under this approach, the ~~Consolidated Statements of Income~~Companies utilized the transition practical expedient to maintain historical presentation for the three and nine months ended September 30, 2018, respectively, resulting in an $0.18 gain per share for both the three and nine months ended September 30, 2018. Virginia Power recorded unrealized gains on equity securities, net of regulatory deferrals, of $15 million ($12 million after-tax) and $13 million ($11 million after-tax), respectively, in other income in the Consolidated Statements of Income for the three and nine months ended September 30, 2018.

~~Derecognition and Partial Sales of Nonfinancial Assets~~

In February 2017, the FASB issued revised accounting guidance clarifying the scope of asset derecognition guidance and accounting for partial sales of nonfinancial assets. The guidance became effective for the Companies’ interim and annual reporting periods ~~beginning~~before January 1, 2018, and the Companies adopted the standard using the modified retrospective method. Upon adoption of the standard, Dominion Energy recorded the cumulative-effect of a change in accounting principle to reclassify $127 million from noncontrolling interests to common stock related to the sale of a noncontrolling interest in certain merchant solar projects completed in December 2015 and January 2016.

~~Net Periodic Pension and Other Postretirement Benefit Costs~~

In March 2017, the FASB issued revised accounting guidance for the presentation of net periodic pension and other postretirement benefit costs. The update requires that the service cost component of net periodic pension and other postretirement benefit costs be classified in the same line item as other compensation costs arising from services rendered by employees, while other components of net periodic pension and other postretirement costs are classified outside of income from operations. In addition, only the service cost component remains eligible for capitalization during construction. These changes do not impact the accounting by participants in a multi-employer plan.

This guidance became effective for the Companies beginning January 1, 2018 with a retrospective adoption for income statement presentation and a prospective adoption for capitalization. Dominion Energy’s and Dominion Energy Gas’ Consolidated Statements of Income for the nine months ended September 30, 2017 have been recast to reflect retrospective adoption for the presentation of the non-service cost component of net periodic pension and other postretirement benefit costs. Previously, the non-service cost component for Dominion Energy and Dominion Energy Gas was reflected in other operations and maintenance in the Consolidated Statements of Income, along with the service cost component of net periodic pension and other postretirement benefit costs. Subsequent to the adoption of this guidance, the non-service cost component of net periodic pension and other postretirement benefit costs is recorded in other income in the Consolidated Statements of Income. As previously reported, Dominion Energy’s other operations and maintenance expense and other income for the three months ended September 30, 2017 were $649 million and $73 million, respectively, and were $2.2 billion and $249 million for the nine months ended September 30, 2017, respectively. Dominion Energy Gas’ other operations and maintenance expense and other income for the three months ended September 30, 2017 were $53 million and $6 million, respectively, and were $312 million and $16 million for the nine months ended September 30, 2017, respectively.

~~Tax Reform~~

In February 2018, the FASB issued revised accounting guidance to provide clarification on the application of the 2017 Tax Reform Act for balances recorded within AOCI. The revised guidance provides for stranded amounts within AOCI from the impacts of the 2017 Tax Reform Act to be reclassified to retained earnings.2019. The Companies ~~adopted this guidance~~also applied the other practical expedients, which required no reassessment of whether existing contracts are or contain leases, no reassessment of lease classification for ~~interim~~existing leases and ~~annual reporting periods beginning January 1, 2018 on a prospective basis.~~no reassessment of existing or expired land easements that were not previously accounted for as leases. In connection with the adoption of this revised accounting guidance, Dominion Energy, ~~reclassified a benefit of $289 million from AOCI to retained earnings,~~ Virginia Power ~~reclassified a benefit of $3 million from AOCI to retained earnings~~ and Dominion Energy Gas ~~reclassified a benefit~~recorded $504 million, $209 million and $64 million, respectively, of ~~$26 million from AOCI to membership interests. The amounts reclassified reflect~~offsetting right-of-use assets and liabilities for operating leases in effect at the ~~reduction in the federal income tax rate, and the federal benefit of state income taxes, on the components of the Companies’ AOCI.~~adoption date. See Note 14 for additional information.

Note 3. Acquisitions and Dispositions

~~Dominion Energy~~

~~Proposed~~ Acquisition of SCANA

~~Under the terms of the SCANA Merger Agreement announced in~~In January ~~2018,~~2019, Dominion Energy ~~has agreed to issue~~issued 95.6 million shares of Dominion Energy common stock, valued at $6.8 billion, representing 0.6690 ~~shares~~of a share of Dominion Energy common stock for each share of SCANA common stock, ~~upon closing.~~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, SCANA markets 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 ~~which currently totals approximately $ 7.1~~totaled $6.9 billion ~~is expected to remain outstanding.~~at closing. The SCANA Combination expanded Dominion Energy’s portfolio of regulated electric generation, transmission and distribution and regulated natural gas distribution infrastructure operations.

Under the original plan filed with the South Carolina Public Service Commission, Dominion Energy will provide the financial support for SCE&G to make a $1.3 billion up-front, one-time rate credit to all current electric service customers of SCE&G to be paid within 90 days of closing and a $575 million refund along with the benefit of the 2017 Tax Reform Act resulting in an approximate 7% reduction to SCE&G electric service customers’ bills over an eight-year period as well as the exclusions from rate recovery of approximately $1.7 billion of costs relatedSee Note 3 to the ~~V.C. Summer Units 2~~Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018 and ~~3 new nuclear development project~~Notes 13, 16 and ~~approximately $180 million to purchase~~17 in this report for more information on the Columbia Energy Center power station. In October 2018, in response to certain stakeholders desiring greater bill reductions over time in lieu of an up-front rate credit, Dominion Energy filed an alternative plan with the South Carolina Public Service Commission that would provide refunds of approximately $1.9 billion over twenty years that along with the benefit of the 2017 Tax Reform Act results in an approximate 14% reduction to SCE&G electric service customer’s bills as well as exclusions from rate recovery of approximately $2.3 billion of costs related to the V.C. Summer Units 2SCANA Combination, including merger approval and ~~3 new nuclear development project~~conditions, information on assets and ~~approximately $180 million to purchase the Columbia Energy Center power station. Dominion Energy supports either of these plans subject to approval by the South Carolina Public Service Commission.~~ liabilities acquired, significant financing transactions, regulatory matters and proceedings, legal proceedings and commitments and contingencies.

Merger Approval and Conditions

Merger Approval

The ~~transaction requires~~SCANA Combination required approval of SCANA’s shareholders, FERC, ~~applicable state commissions~~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. In January 2018, SCANA and Dominion Energy filed for review and approval from the South Carolina Public Service Commission, the North Carolina Utilities Commission, the Georgia Public Service Commission and the NRC. In February 2018, the Federal Trade Commission granted early terminationAll such approvals were received prior to closing of the ~~waiting period under the Hart-Scott-Rodino Act. Also in February 2018, Dominion Energy and~~ SCANA Combination.

Various parties filed petitions for review and approval by FERC. In March 2018, the Georgia Public Service Commission approved the proposed merger. In July 2018, FERC and SCANA’s shareholders approved the proposed merger. In September 2018, the NRC approved the proposed merger. Dominion Energy is not required to accept an order by the South Carolina Public Service Commission approving Dominion Energy’s merger with SCANA if such order contains any material change to the terms, conditionsrehearing or undertakings set forth in the cost recovery plan related to the V.C. Summer Units 2 and 3 new nuclear development project or any significant changes to the economic value of the cost recovery plan. In addition, the SCANA Merger Agreement provides that Dominion Energy will have the right to refuse to close the merger if there shall have occurred any substantive change in the Base Load Review Act or other laws governing South Carolina public utilities which has or would reasonably be expected to have an adverse effect on SCE&G. The SCANA Merger Agreement contains certain termination rights for both Dominion Energy and SCANA, and provides that, upon terminationreconsideration of the SCANA Merger ~~Agreement under specified circumstances,~~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 Commission 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 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 would~~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 is 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 ~~pay~~satisfy any liens against NND Project property totaling $1.0 billion, will be refunded to DESC electric service customers over a ~~termination fee~~20-year period ending in 2039.

Additionally, in the first quarter of ~~$280~~2019, DESC recorded a reduction in operating revenue and a corresponding regulatory liability of $1.0 billion, of which $137 million is 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 of Income for the three months ended March 31, 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 is 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 ~~would be required to pay~~ 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

•

DESC will not file an application for 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;

Dominion Energy ~~a termination fee~~has committed to increasing SCANA’s historical level of ~~$240 million. Subject~~corporate contributions to ~~receipt of required regulatory approvals and meeting closing conditions,~~ charities by $1 million per year over the next five years;

Dominion Energy ~~targets closing by the end of 2018.~~will maintain DESC and PSNC’s headquarters in Cayce, South Carolina and Gastonia, North Carolina, respectively; and

~~Wholly-Owned Merchant Solar Projects~~

~~In August 2016,~~ Dominion Energy ~~entered into an agreement~~will seek to ~~acquire 100% of the equity interests of two solar projects~~minimize reductions in California from Solar Frontier Americas Holding LLC for cash consideration. In March 2017, Dominion Energy closed on the acquisition of one of the solar projects for $77 million, all of which was allocatedlocal employment by allowing some DES employees supporting shared and common services functions and activities to ~~property, plant~~be located in Cayce, South Carolina where it makes economic and ~~equipment. The facility commenced commercial operations in June 2017, at a cost of $78 million, including the initial acquisition cost,~~practical sense to do so.

Purchase Price Allocation

SCANA’s assets acquired and ~~generates approximately 30 MW. In April 2017, Dominion Energy discontinued efforts on the acquisition of the additional 20 MW solar project from Solar Frontier Americas Holding LLC.~~

In September 2016, Dominion Energy entered into an agreement to acquire 100% of the equity interests of a solar project in Virginia from Community Energy Solar, LLC for cash consideration. In February 2017, Dominion Energy closed on the acquisition for $29 million, all of which was allocated to property, plant and equipment. The facility commenced commercial operations in December 2017, at a cost of $205 million, including the initial acquisition cost, and generates approximately 100 MW.

In January 2017, Dominion Energy entered into an agreement to acquire 100% of the equity interests of a solar project in North Carolina from Cypress Creek Renewables, LLC for cash consideration. In May 2017, Dominion Energy closed on the acquisition for $154 million, all of which was allocated to property, plant and equipment. The facility commenced commercial operations in June 2017, at a cost of $160 million, including the initial acquisition cost, and generates approximately 79 MW.

In May 2017, Dominion Energy entered into an agreement to acquire 100% of the equity interests of two solar projects in Virginia from Hecate Energy Virginia C&C LLC for cash consideration of $56 million. Dominion Energy completed the acquisition of one of

the projects in June 2017 for $16 million and the facility commenced commercial operations in August 2017. The second acquisition was completed in September 2017 for $40 million and the facility commenced commercial operations in November 2017. The projects cost $57 million, including initial acquisition costs, and generate approximately 30 MW combined.

In June 2017, Dominion Energy entered into an agreement to acquire 100% of the equity interests of four solar projects in North Carolina from Strata Solar Development, LLC and Moorings Farm 2 Holdco, LLC for cash consideration of $40 million. Dominion Energy completed the acquisition of two of the projects in June 2017 at a cost of $20 million. The final two acquisitions were completed in October 2017 for $20 million. The projects commenced commercial operations in November 2017 at a cost of $41 million, including the initial acquisition costs, and generate approximately 20 MW combined.

~~Long-term power purchase, interconnection and operation and maintenance agreements~~liabilities assumed have been ~~executed for all of the projects described above. These projects~~measured at estimated fair value at closing and are included in ~~Power Generation.~~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 an adjustment related to income taxes identified during the first quarter 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⁾		$	1,772
Investments			224
Property, plant and equipment⁽²⁾			11,006
Goodwill			2,550
Regulatory assets⁽³⁾			3,940
Other deferred charges and other assets, including intangible assets			430
Total Assets			19,922
Total current liabilities			1,515
Long-term debt			6,707
Deferred income taxes			1,100
Regulatory liabilities			2,662
Other deferred credits and other liabilities			1,099
Total Liabilities			13,083
Total purchase price⁽⁴⁾		$	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. As a result, Dominion Energy’s Consolidated Statement of Income for the three months ended March 31, 2019 includes a charge of $105 million ($79 million after-tax), included in impairment of assets and other charges.

(3)	Includes $264 million of certain income tax-related regulatory assets associated with the NND Project for which Dominion Energy committed to forgo recovery in accordance with the SCANA Merger Approval Order. See Note 5 for additional information.

(4)	Includes stock-based compensation awards with an estimated fair value of $21 million.

See Note 3 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K 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 and net income attributable to Dominion Energy in the Consolidated Statements of Income for the three months ended March 31, 2019 was an increase of $170 million and a decrease of $1.1 billion, respectively.

Dominion Energy incurred merger and integration-related costs, of which $115 million was recorded in other operations and maintenance expense and $9 million was recorded in interest and related charges in the Consolidated Statements of Income for the three months ended March 31, 2019. These costs consist of professional fees, the charitable contribution commitment described above, 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 ~~claimed federal investment tax credits on these solar projects.~~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 March 31,
	2019⁽¹⁾		2018⁽¹⁾
(millions, except EPS)
Operating Revenue	$	4,887	$	4,636
Net income attributable to Dominion Energy		605		675
Earnings Per Common Share – Basic	$	0.76	$	0.90
Earnings Per Common Share – Diluted	$	0.76	$	0.90

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

Note 4. Operating Revenue

The Companies’ operating revenue ~~subsequent to the adoption of revised guidance for revenue recognition from contracts with customers,~~ consists of the following:

	Three Months Ended September 30,		Nine Months Ended September 30,		Three Months Ended March 31,
	2018		2018		2019		2018
(millions)
Dominion Energy
Regulated electric sales:
Residential	$	1,036	$	2,641	$	646	$	817
Commercial		737		1,897		496		524
Industrial		143		371		30		107
Government and other retail		224		647		200		213
Wholesale		30		95		48		42
Nonregulated electric sales		322		1,022		316		418
Regulated gas sales:
Residential		73		553		602		364
Commercial		15		152		191		103
Other		3		14		38		10
Nonregulated gas sales		42		139		247		88
Regulated gas transportation and storage:
FERC-regulated		266		800		277		262
State-regulated		138		472		213		190
Nonregulated gas transportation and storage		162		286		174		—
Other regulated revenues		38		132
Other regulated revenues⁽¹⁾						58		50
Other nonregulated revenues⁽¹⁾⁽²⁾		133		410		95		136
Total operating revenue from contracts with customers		3,362		9,631		3,631		3,324
Other revenues⁽²⁾⁽³⁾		89		374		227		142
Total operating revenue	$	3,451	$	10,005	$	3,858	$	3,466
Virginia Power
Regulated electric sales:
Residential	$	1,036	$	2,641	$	923	$	817
Commercial		737		1,897		636		524
Industrial		143		371		112		107
Government and other retail		224		647		204		213
Wholesale		30		95		37		42
Other regulated revenues		30		95		33		32
Other nonregulated revenues⁽¹⁾⁽²⁾		10		41
Other nonregulated revenues⁽²⁾						6		13
Total operating revenue from contracts with customers		2,210		5,787		1,951		1,748
Other revenues⁽²⁾⁽³⁾		22		22		14		—
Total operating revenue	$	2,232	$	5,809	$	1,965	$	1,748
Dominion Energy Gas
Regulated gas sales:
Residential	$	12	$	54	$	30	$	29
Other		—		9		2		7
Nonregulated gas sales⁽¹⁾⁽²⁾		2		5		2		2
Regulated gas transportation and storage:
FERC-regulated⁽¹⁾⁽²⁾		179		561		204		199
State-regulated⁽¹⁾⁽²⁾		131		450		187		180
NGL revenue⁽¹⁾⁽²⁾		42		146		45		54
Management service revenue⁽¹⁾⁽²⁾		50		157		31		47
Other regulated revenues⁽¹⁾⁽²⁾		4		16		8		8
Other nonregulated revenues⁽¹⁾⁽²⁾		3		9		2		2
Total operating revenue from contracts with customers		423		1,407		511		528
Other revenues		—		1		—		(2	)
Total operating revenue	$	423	$	1,408	$	511	$	526

(1)	~~See Notes 10 and 18 for amounts attributable to related parties and affiliates.~~

~~(2)~~

Amounts above include ~~$108~~$51 million and ~~$91~~$42 million for the three months ended ~~September 30, 2018,~~March 31, 2019, and ~~$170~~$30 million and ~~$138~~$26 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2018 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~~

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

(3)

Amounts above include ~~$10~~$14 million and ~~$11~~$8 million of ~~sales of renewable energy investment tax credits~~alternative revenue 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.~~March 31, 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, 2018	2018		2019		2020		2021		2022		Thereafter		Total
Revenue expected to be recognized on multi-year contracts in place at March 31, 2019															2019		2020		2021		2022		2023		Thereafter		Total
(millions)
Dominion Energy	$	430	$	1,672	$	1,568	$	1,454	$	1,324	$	13,799	$	20,247	$	1,197	$	1,547	$	1,448	$	1,334	$	1,166	$	13,562	$	20,254
Virginia Power		5		21		3		1		—		—		30		16		3		1		—		—		—		20
Dominion Energy Gas		170		633		574		489		397		2,171		4,434		476		623		545		441		317		1,928		4,330

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 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Dominion Energy’s contract asset balances were ~~$44~~$40 million and ~~$46~~$42 million, respectively. Dominion Energy Gas’ contract asset balances were ~~$61~~$55 million and ~~$66~~$58 million at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, 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 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Dominion Energy’s contract liability balances were ~~$102~~$77 million and ~~$132~~$106 million, respectively. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Virginia Power’s contract liability balances were ~~$20~~$21 million and ~~$50~~$22 million, respectively. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Dominion Energy Gas’ contract liability balances were ~~$38~~$15 million and ~~$41~~$40 million, respectively. During the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, Dominion Energy, Virginia Power and Dominion Energy Gas recognized revenue of ~~$93~~$85 million, ~~$25~~$22 million and ~~$40~~$36 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’ operating revenue, prior to the adoption of revised guidance for revenue recognition from contracts with customers, consisted of the following:~~

Three Months Ended September 30,

Nine Months Ended September 30,

2017

2017

(millions)

Dominion Energy

Electric sales:

Regulated

$
2,108

$
5,590

Nonregulated

380

1,114

Gas sales:

Regulated

97

696

Nonregulated

69

323

Gas transportation and storage

406

1,328

Other

119

325

Total operating revenue

$
3,179

$
9,376

Virginia Power

Regulated electric sales

$
2,108

$
5,590

Other

46

142

Total operating revenue

$
2,154

$
5,732

Dominion Energy Gas

Gas sales:

Regulated

$
12

$
59

Nonregulated

2

12

Gas transportation and storage

324

1,062

Other

63

180

Total operating revenue

$
401

$
1,313

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,	2018			2017			2018			2017			2018			2017
Three Months Ended March 31,																			2019			2018			2019			2018			2019			2018
U.S. statutory rate		21.0	%		35.0	%		21.0	%		35.0	%		21.0	%		35.0	%		21.0	%		21.0	%		21.0	%		21.0	%		21.0	%		21.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit		3.3			2.9			4.6			3.7			3.9			2.7			2.2			4.1			4.6			4.5			3.4			4.3
Investment tax credits		(0.9	)		(5.7	)		(1.4	)		(0.8	)		—			—			(1.5	)		(0.5	)		(3.2	)		(0.9	)		—			—
Production tax credits		(0.7	)		(0.7	)		(0.7	)		(0.5	)		—			—			(0.8	)		(0.6	)		(1.0	)		(0.7	)		—			—
Reversal of excess deferred income taxes		(1.5	)		—			(1.9	)		—			(1.3	)		—			(5.1	)		(1.4	)		(5.0	)		(2.0	)		(1.1	)		(1.0	)
Federal legislative change		2.0			—			(0.2	)		—			2.0			—
State legislative change		(0.8	)		—			—			—			0.1			—
AFUDC - equity		(0.9	)		(1.3	)		(0.5	)		(0.6	)		(0.4	)		(0.8	)
Write-off of regulatory assets																				(34.1	)		—			—			—			—			—
Other, net		(1.0	)		(2.6	)		(0.3	)		0.2			0.7			(0.1	)		(2.0	)		(2.1	)		0.1			(0.3	)		(0.3	)		(0.4	)
Effective tax rate		20.5	%		27.6	%		20.6	%		37.0	%		26.0	%		36.8	%		(20.3	)%		20.5	%		16.5	%		21.6	%		23.0	%		23.9	%

The 2017 Tax Reform Act reduced the statutory federal income tax rate to 21% beginning in January 2018. Accordingly, current income taxes, and deferred income taxes that originate in 2018, are being recorded at the new 21% rate. 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%. ~~For the three and nine months ended September 30, 2018, the~~The Companies have recorded an estimate of the portion of excess deferred income tax amortization ~~expected to occur~~ in ~~2018.~~2019. 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 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.

In ~~addition,~~connection with the SCANA Combination, Dominion Energy ~~and Dominion Energy Gas’ effective tax rates reflect~~committed to forgo, or limit, the ~~impacts~~recovery of ~~a state legislative change enacted in~~certain income tax-related regulatory assets associated with the ~~second quarter of 2018 that was retroactive to January 1, 2018.~~

Beginning in 2018, 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 issued regulations, the Companies expect interest expense to be deductible in 2018.

The Companies continue to evaluate the changes in accelerated depreciation for income tax purposes and state conformity to the provisions of the 2017 Tax Reform Act. As of September 30, 2018, the Companies have applied the provisions of recently proposed regulations addressing the availability of federal bonus depreciation for the period beginning after September 27, 2017 through December 31, 2017. The application of these changes decreased Dominion Energy’s net operating loss carryforward utilization on the 2017 tax return. As a result,NND Project. Dominion Energy’s effective tax rate reflects ~~a $23 million increase to~~ deferred income tax expense ~~associated with the remeasurement~~of $198 million in satisfaction of this ~~deferred~~commitment. Dominion Energy’s effective tax ~~asset as more federal net operating loss carryforwards will be utilized at~~rate also reflects the ~~21% rate. The application~~changes in consolidated state income taxes resulting from the SCANA Combination.

As part of ~~these proposed regulations at~~the SCANA Combination, Dominion Energy ~~Gas~~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. This adjustment resulted in an increase to goodwill of $40 million and had no impact on Dominion Energy’s income tax ~~expense as the changes in, and remeasurement of, deferred~~expense. It is reasonably possible that settlement negotiations could decrease this unrecognized tax liabilities increased regulatory liabilities by $35 million. The effects of these changes at Virginia Power were immaterial. These amounts and adjustments represent the Companies’ best estimate based on available information, and could be subject to change based on additional guidance in yet to be finalized regulations. In addition, changes in estimates of amounts probable of return to customers increased income tax expense at Dominion Energy and Dominion Energy Gas by $8 million, and regulatory liabilities by $11 million. See Note 5 to the Consolidated Financial Statementsbenefit in the ~~Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, for a discussion of the impacts of the 2017 Tax Reform Act.~~next twelve months.

As of ~~September 30, 2018,~~March 31, 2019, 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018, 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 March 31,
	2018		2017		2018		2017		2019			2018
(millions, except EPS)
Net income attributable to Dominion Energy	$	854	$	665	$	1,806	$	1,687
Net income (loss) attributable to Dominion Energy									$	(680	)	$	503
Average shares of common stock outstanding – Basic		653.9		642.5		652.4		633.4		793.1			650.5
Net effect of dilutive securities		1.0		—		0.4		—		—			—
Average shares of common stock outstanding – Diluted		654.9		642.5		652.8		633.4		793.1			650.5
Earnings Per Common Share – Basic	$	1.31	$	1.03	$	2.77	$	2.66	$	(0.86	)	$	0.77
Earnings Per Common Share – Diluted	$	1.30	$	1.03	$	2.77	$	2.66	$	(0.86	)	$	0.77

~~Dilutive~~As a result of a net loss for the three months ended March 31, 2019, the issuance of common stock under potentially-dilutive securities ~~consist primarily~~was considered antidilutive and therefore excluded from the calculation of ~~forward sales agreements, effective April 2018. See Note 15 for more information regarding the forward sales agreements. In calculating the~~ diluted ~~EPS in connection with the forward sales agreements, Dominion Energy applies the treasury stock method.~~

EPS. The ~~2014~~2016 Equity Units ~~were potentially dilutive securities, but~~ were excluded from the calculation of diluted EPS for the three ~~and nine~~ months ended September 30, 2017, as the diluted stock price threshold was not met. The 2016 Equity Units are potentially dilutive securities, but were excluded from the calculation of diluted EPS for the three and nine months ended September 30,March 31, 2018, ~~and 2017,~~ as the dilutive stock price threshold was not met. The Dominion Energy Midstream convertible preferred units ~~are~~were potentially dilutive securities but had no effect on the calculation of diluted EPS for the three ~~and nine~~ months ended ~~September 30,~~March 31, 2018 ~~and 2017~~. ~~In calculating diluted EPS in connection with the Dominion Energy Midstream convertible preferred units, Dominion Energy applies 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, 2018
Three Months Ended March 31, 2019
Beginning balance	$	(248	)	$	(2	)	$	(1,286	)	$	(2	)	$	(1,538	)	$	(235	)	$	2		$	(1,465	)	$	(2	)	$	(1,700	)
Other comprehensive income before reclassifications: gains (losses)		(27	)		(6	)		—			—			(33	)		(24	)		16			—			—			(8	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		30			3			18			—			51			(31	)		—			8			—			(23	)
Net current period other comprehensive income (loss)		3			(3	)		18			—			18			(55	)		16			8			—			(31	)
Ending balance	$	(245	)	$	(5	)	$	(1,268	)	$	(2	)	$	(1,520	)	$	(290	)	$	18		$	(1,457	)	$	(2	)	$	(1,731	)
Three Months Ended September 30, 2017
Beginning balance	$	(250	)	$	630		$	(1,058	)	$	(4	)	$	(682	)
Other comprehensive income before reclassifications: gains (losses)		11			48			—			—			59
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(15	)		(4	)		14			—			(5	)
Net current period other comprehensive income (loss)		(4	)		44			14			—			54
Ending balance	$	(254	)	$	674		$	(1,044	)	$	(4	)	$	(628	)
Nine Months Ended September 30, 2018
Three Months Ended March 31, 2018
Beginning balance	$	(302	)	$	747		$	(1,101	)	$	(3	)	$	(659	)	$	(302	)	$	747		$	(1,101	)	$	(3	)	$	(659	)
Other comprehensive income before reclassifications: gains (losses)		51			(24	)		—			1			28			111			(13	)		—			—			98
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		71			4			60			—			135			8			1			25			—			34
Net current period other comprehensive income (loss)		122			(20	)		60			1			163			119			(12	)		25			—			132
Cumulative-effect of changes in accounting principle		(64	)		(732	)		(227	)		—			(1,023	)		(64	)		(732	)		(227	)		—			(1,023	)
Less other comprehensive income attributable to noncontrolling interest		1			—			—			—			1			1			—			—			—			1
Ending balance	$	(245	)	$	(5	)	$	(1,268	)	$	(2	)	$	(1,520	)	$	(248	)	$	3		$	(1,303	)	$	(3	)	$	(1,551	)
Nine Months Ended September 30, 2017
Beginning balance	$	(280	)	$	569		$	(1,082	)	$	(6	)	$	(799	)
Other comprehensive income before reclassifications: gains (losses)		82			141			—			2			225
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(56	)		(36	)		38			—			(54	)
Net current period other comprehensive income (loss)		26			105			38			2			171
Ending balance	$	(254	)	$	674		$	(1,044	)	$	(4	)	$	(628	)

(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 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

Three Months Ended September 30, 2017

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

Commodity contracts

$
(32
)

Operating revenue

1

Electric fuel and other energy-related purchases
Interest rate contracts

16

Interest and related charges
Foreign currency contracts

(10
)

Other income
Total

(25
)

Tax

10

Income tax expense
Total, net of tax

$
(15
)

Unrealized (gains) and losses on investment securities:

Realized (gain) loss on sale of securities

$
(10
)

Other income
Impairment

4

Other income
Total

(6
)

Tax

2

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

26

Other income
Total

21

Tax

(7
)

Income tax expense
Total, net of tax

$
14

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

Details about AOCI components					Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Three Months Ended March 31, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts					$	(54	)	Operating revenue
						(3	)	Purchased gas
Interest rate contracts						10		Interest and related charges
Foreign currency contracts						6		Other income
Total						(41	)
Tax						10		Income tax expense
Total, net of tax					$	(31	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)					$	(5	)	Other income
Amortization of actuarial losses						27		Other income
Total						22
Tax						(14	)	Income tax expense
Total, net of tax					$	8
Three Months Ended March 31, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts					$	12		Operating revenue
						2		Purchased gas
						(7	)	Electric fuel and other energy-related purchases
Interest rate contracts						12		Interest and related charges
Foreign currency contracts		10		Other income		(8	)	Other income
Total		95				11
Tax		(24	)	Income tax expense		(3	)	Income tax expense
Total, net of tax	$	71			$	8
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	5		Other income	$	1		Other income
Total		5				1
Tax		(1	)	Income tax expense		—		Income tax expense
Total, net of tax	$	4			$	1
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(16	)	Other income	$	(5	)	Other income
Amortization of actuarial losses		91		Other income		31		Other income
Total		75				26
Tax		(15	)	Income tax expense		(1	)	Income tax expense
Total, net of tax	$	60			$	25
Nine Months Ended September 30, 2017
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(114	)	Operating revenue
		(1	)	Electric fuel and other energy-related purchases
Interest rate contracts		39		Interest and related charges
Foreign currency contracts		(15	)	Other income
Total		(91	)
Tax		35		Income tax expense
Total, net of tax	$	(56	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(74	)	Other income
Impairment		18		Other income
Total		(56	)
Tax		20		Income tax expense
Total, net of tax	$	(36	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(16	)	Other income
Amortization of actuarial losses		79		Other income
Total		63
Tax		(25	)	Income tax expense
Total, net of tax	$	38

Virginia Power

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

Deferred gains
and losses on
derivatives-
hedging
activities

Unrealized gains
and losses on
investment
securities

Total

(millions)

Three Months Ended September 30, 2018

Beginning balance

$
(8
)

$
(1
)

$
(9
)
Other comprehensive income before reclassifications:
   gains (losses)

3

—

3

Amounts reclassified from AOCI: (gains) losses

—

—

—

Net current period other comprehensive income (loss)

3

—

3

Ending balance

$
(5
)

$
(1
)

$
(6
)
Three Months Ended September 30, 2017

Beginning balance

$
(10
)

$
61

$
51

Other comprehensive income before reclassifications:
   gains (losses)

(2
)

6

4

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

—

—

—

Net current period other comprehensive income (loss)

(2
)

6

4

Ending balance

$
(12
)

$
67

$
55

Nine Months Ended September 30, 2018

Beginning balance

$
(12
)

$
74

$
62

Other comprehensive income before reclassifications:
   gains (losses)

10

(2
)

8

Amounts reclassified from AOCI: (gains) losses

—

—

—

Net current period other comprehensive income (loss)

10

(2
)

8

Cumulative-effect of changes in accounting principle

(3
)

(73
)

(76
)
Ending balance

$
(5
)

$
(1
)

$
(6
)
Nine Months Ended September 30, 2017

Beginning balance

$
(8
)

$
54

$
46

Other comprehensive income before reclassifications:
   gains (losses)

(5
)

17

12

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

1

(4
)

(3
)
Net current period other comprehensive income (loss)

(4
)

13

9

Ending balance

$
(12
)

$
67

$
55

~~(1)~~

~~See table below for details about these reclassifications.~~

	Deferred gains and losses on derivatives- hedging activities			Unrealized gains and losses on investment securities			Total
(millions)
Three Months Ended March 31, 2019
Beginning balance	$	(13	)	$	1		$	(12	)
Other comprehensive income before reclassifications: gains (losses)		(7	)		2			(5	)
Amounts reclassified from AOCI: (gains) losses		—			—			—
Net current period other comprehensive income (loss)		(7	)		2			(5	)
Ending balance	$	(20	)	$	3		$	(17	)
Three Months Ended March 31, 2018
Beginning balance	$	(12	)	$	74		$	62
Other comprehensive income before reclassifications: gains (losses)		5			—			5
Amounts reclassified from AOCI: (gains) losses		—			—			—
Net current period other comprehensive income (loss)		5			—			5
Cumulative-effect of changes in accounting principle		(3	)		(73	)		(76	)
Ending balance	$	(10	)	$	1		$	(9	)

The following table presents Virginia Power’s reclassifications out of AOCI by component. Reclassifications out of AOCI were immaterial for both the three months ended September 30, 2017 and 2018 and the nine months ended September 30, 2018.

Details about AOCI components

Amounts
reclassified
from AOCI

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

Nine Months Ended September 30, 2017

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

Interest rate contracts

$
1

Interest and related charges
Total

1

Tax

—

Income tax expense
Total, net of tax

$
1

Unrealized (gains) and losses on investment securities:

Realized (gain) loss on sale of securities

$
(8
)

Other income
Impairment

2

Other income
Total

(6
)

Tax

2

Income tax expense
Total, net of tax

$
(4
)

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, 2018
Three Months Ended March 31, 2019
Beginning balance	$	(24	)	$	(94	)	$	(118	)	$	(25	)	$	(144	)	$	(169	)
Other comprehensive income before reclassifications: gains (losses)		3			—			3			(27	)		—			(27	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		5			2			7			4			1			5
Net current period other comprehensive income (loss)		8			2			10			(23	)		1			(22	)
Ending balance	$	(16	)	$	(92	)	$	(108	)	$	(48	)	$	(143	)	$	(191	)
Three Months Ended September 30, 2017
Three Months Ended March 31, 2018
Beginning balance	$	(23	)	$	(97	)	$	(120	)	$	(23	)	$	(75	)	$	(98	)
Other comprehensive income before reclassifications: gains (losses)		1			—			1			13			—			13
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(4	)		1			(3	)		(3	)		1			(2	)
Net current period other comprehensive income (loss)		(3	)		1			(2	)
Ending balance	$	(26	)	$	(96	)	$	(122	)
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
Net current period other comprehensive income											10			1			11
Cumulative-effect of changes in accounting principle		(5	)		(21	)		(26	)		(5	)		(21	)		(26	)
Ending balance	$	(16	)	$	(92	)	$	(108	)	$	(18	)	$	(95	)	$	(113	)
Nine Months Ended September 30, 2017
Beginning balance	$	(24	)	$	(99	)	$	(123	)
Other comprehensive income before reclassifications: gains (losses)		3			—			3
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(5	)		3			(2	)
Net current period other comprehensive income (loss)		(2	)		3			1
Ending balance	$	(26	)	$	(96	)	$	(122	)

(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, 2018
Three Months Ended March 31, 2019
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	3		Operating revenue	$	(2	)	Operating revenue
Interest rate contracts		2		Interest and related charges		1		Interest and related charges
Foreign currency contracts		2		Other income		6		Other income
Total		7				5
Tax		(2	)	Income tax expense		(1	)	Income tax expense
Total, net of tax	$	5			$	4
Unrecognized pension costs:
Actuarial losses	$	2		Other income	$	2		Other income
Total		2				2
Tax		—		Income tax expense		(1	)	Income tax expense
Total, net of tax	$	2			$	1
Three Months Ended September 30, 2017
Three Months Ended March 31, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	2		Operating revenue	$	3		Operating revenue
Interest rate contracts		1		Interest and related charges		1		Interest and related charges
Foreign currency contracts		(10	)	Other income		(8	)	Other income
Total		(7	)			(4	)
Tax		3		Income tax expense		1		Income tax expense
Total, net of tax	$	(4	)		$	(3	)
Unrecognized pension costs:
Actuarial losses	$	2		Other income	$	2		Other income
Total		2				2
Tax		(1	)	Income tax expense		(1	)	Income tax expense
Total, net of tax	$	1			$	1
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	$	4
Nine Months Ended September 30, 2017
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	4		Operating revenue
Interest rate contracts		3		Interest and related charges
Foreign currency contracts		(15	)	Other income
Total		(8	)
Tax		3		Income tax expense

Total, net of tax

$
(5
)

Unrecognized pension costs:

Actuarial losses

$
5

Other income
Total

5

Tax

(2
)

Income tax expense
Total, net of tax

$
3

Note 8. Fair Value Measurements

The Companies’ fair value measurements are made in accordance with the policies discussed in Note 6 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018. 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 unobservable inputs are developed and substantiated using historical information, available market data, third-party data, and statistical analysis. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changes in third-party pricing sources.

The following table presents Dominion Energy’s quantitative information about Level 3 fair value measurements at ~~September 30, 2018.~~March 31, 2019. 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:
Natural gas⁽²⁾	$	65	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 7		—		$	60	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 7		(1	)
FTRs		12	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 7		1			2	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 2		—
Physical options:
Natural gas		2	Option model	Market price (per Dth)	⁽³⁾	1 - 7		3			1	Option model	Market price (per Dth)	⁽³⁾	2 - 7		3
				Price volatility	⁽⁴⁾	13% - 44%		23	%				Price volatility	⁽⁴⁾	10% - 492%		66	%
Electricity		19	Option model	Market price (per MWh)	⁽³⁾	27 - 57		42
				Price volatility	⁽⁴⁾	4% - 61%		37	%
Total assets	$	98								$	63
Liabilities
Financial forwards:
FTRs	$	6	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 6		—		$	3	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 2		1
Physical options:
Natural gas											7	Option model	Market price (per Dth)	⁽³⁾	2 - 16		5
													Price volatility	⁽⁴⁾	23% - 492%		82	%
Total liabilities	$	6								$	10

(1)	Averages weighted by volume.

(2)	Includes basis.

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

(4)	Represents volatilities unrepresented in published markets.

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, 2018
At March 31, 2019
Assets
Derivatives:
Commodity	$	—	$	50	$	98	$	148	$	2	$	92	$	63	$	157
Interest rate		—		117		—		117		—		3		—		3
Foreign currency		—		32		—		32		—		13		—		13
Investments⁽¹⁾:
Equity securities:
U.S.		3,785		—		—		3,785		3,688		—		—		3,688
Fixed income securities:
Corporate debt instruments		—		437		—		437		—		470		—		470
Government securities		350		768		—		1,118		468		678		—		1,146
Cash equivalents and other		13		—		—		13		11		—		—		11
Total assets	$	4,148	$	1,404	$	98	$	5,650	$	4,169	$	1,256	$	63	$	5,488
Liabilities
Derivatives:
Commodity	$	—	$	94	$	6	$	100	$	—	$	35	$	10	$	45
Interest rate		—		42		—		42		—		323		—		323
Foreign currency		—		3		—		3		—		1		—		1
Total liabilities	$	—	$	139	$	6	$	145	$	—	$	359	$	10	$	369
At December 31, 2017
At December 31, 2018
Assets
Derivatives:
Commodity	$	—	$	101	$	157	$	258	$	—	$	180	$	70	$	250
Interest rate		—		17		—		17		—		18		—		18
Foreign currency		—		32		—		32		—		26		—		26
Investments⁽¹⁾:
Equity securities:
U.S.		3,493		—		—		3,493		3,277		—		—		3,277
Fixed income securities:
Corporate debt instruments		—		444		—		444		—		431		—		431
Government securities		307		794		—		1,101		455		688		—		1,143
Cash equivalents and other		34		—		—		34		11		—		—		11
Total assets	$	3,834	$	1,388	$	157	$	5,379	$	3,743	$	1,343	$	70	$	5,156
Liabilities
Derivatives:
Commodity	$	—	$	190	$	7	$	197	$	—	$	129	$	6	$	135
Interest rate		—		85		—		85		—		142		—		142
Foreign currency		—		2		—		2		—		2		—		2
Total liabilities	$	—	$	277	$	7	$	284	$	—	$	273	$	6	$	279

(1)

Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes ~~$217~~$213 million and ~~$88~~$220 million of assets at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, 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
	September 30,						September 30,						March 31,
	2018			2017			2018			2017			2019			2018
(millions)
Beginning balance	$	119		$	152		$	150		$	139		$	64		$	150
Total realized and unrealized gains (losses):
Included in earnings		(7	)		(11	)		(27	)		(36	)
Included in earnings:
Operating revenue														(1	)		(1	)
Electric fuel and other energy-related purchases														(4	)		(17	)
Included in other comprehensive income		—			—			1			—			—			1
Included in regulatory assets/liabilities		(16	)		11			(26	)		34			7			(21	)
Settlements		(4	)		1			(7	)		13			(1	)		7
Purchases														(10	)		—
Transfers out of Level 3		—			—			1			3			(2	)		1
Ending balance	$	92		$	153		$	92		$	153		$	53		$	120
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	$	—		$	1		$	—		$	1

The ~~following table presents Dominion Energy’s classification of~~unrealized gains ~~and~~or losses included in earnings in the Level 3 fair value ~~category.~~category relating to assets/liabilities still held at the reporting date were not material for the three months ended March 31, 2019 and 2018.

Operating
Revenue

Electric Fuel
and Other
Energy-Related
Purchases

Total

(millions)

Three Months Ended September 30, 2018

Total gains (losses) included in earnings

$
—

$
(7
)

$
(7
)
Three Months Ended September 30, 2017

Total gains (losses) included in earnings

$
1

$
(12
)

$
(11
)
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

1

—

1

Nine Months Ended September 30, 2018

Total gains (losses) included in earnings

$
(2
)

$
(25
)

$
(27
)
Nine Months Ended September 30, 2017

Total gains (losses) included in earnings

$
1

$
(37
)

$
(36
)
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

1

—

1

Virginia Power

The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at ~~September 30, 2018.~~March 31, 2019. 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:
Natural gas⁽²⁾	$	58	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 7		(1	)	$	59	Discounted cash flow	Market price (per Dth)	⁽³⁾	(2) - 7		(1	)
FTRs		12	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 7		1			2	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 2		—
Physical options:
Natural gas		2	Option model	Market price (per Dth)	⁽³⁾	1 - 7		3			1	Option model	Market price (per Dth)	⁽³⁾	2 - 7		2
				Price volatility	⁽⁴⁾	13% - 44%		23	%				Price volatility	⁽⁴⁾	10% - 491%		54	%
Electricity		19	Option model	Market price (per MWh)	⁽³⁾	27 - 57		42
				Price volatility	⁽⁴⁾	4% - 61%		37	%
Total assets	$	91								$	62
Liabilities
Financial forwards:
FTRs	$	5	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 6		—		$	3	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 2		1
Total liabilities	$	5								$	3

(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, 2018
At March 31, 2019
Assets
Derivatives:
Commodity									$	—	$	4	$	62	$	66
Investments⁽¹⁾:
Equity securities:
U.S.										1,683		—		—		1,683
Fixed income securities:
Corporate debt instruments										—		233		—		233
Government securities										192		328		—		520
Total assets									$	1,875	$	565	$	62	$	2,502
Liabilities
Derivatives:
Commodity									$	—	$	6	$	3	$	9
Interest rate										—		181		—		181
Total liabilities									$	—	$	187	$	3	$	190
At December 31, 2018
Assets
Derivatives:
Commodity	$	—	$	14	$	91	$	105	$	—	$	24	$	66	$	90
Interest rate		—		65		—		65		—		3		—		3
Investments⁽¹⁾:
Equity securities:
U.S.		1,699		—		—		1,699		1,476		—		—		1,476
Fixed income securities:
Corporate debt instruments		—		218		—		218		—		221		—		221
Government securities		158		348		—		506		164		343		—		507
Total assets	$	1,857	$	645	$	91	$	2,593	$	1,640	$	591	$	66	$	2,297
Liabilities
Derivatives:
Commodity	$	—	$	3	$	5	$	8	$	—	$	9	$	6	$	15
Total liabilities	$	—	$	3	$	5	$	8
At December 31, 2017
Assets
Derivatives:
Commodity	$	—	$	14	$	152	$	166
Investments⁽¹⁾:
Equity securities:
U.S.		1,566		—		—		1,566
Fixed income securities:
Corporate debt instruments		—		224		—		224
Government securities		168		326		—		494
Cash equivalents and other		16		—		—		16
Total assets	$	1,750	$	564	$	152	$	2,466
Liabilities
Derivatives:
Commodity	$	—	$	4	$	5	$	9
Interest rate		—		57		—		57		—		88		—		88
Total liabilities	$	—	$	61	$	5	$	66	$	—	$	97	$	6	$	103

(1)

Includes investments held in the nuclear decommissioning trusts. Excludes ~~$151~~$150 million and ~~$27~~$160 million of assets at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, 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
	September 30,						September 30,						March 31,
	2018			2017			2018			2017			2019			2018
(millions)
Beginning balance	$	115		$	152		$	147		$	143		$	60		$	147
Total realized and unrealized gains (losses):
Included in earnings		(6	)		(12	)		(25	)		(37	)
Included in earnings:
Electric fuel and other energy-related purchases														(4	)		(17	)
Included in regulatory assets/liabilities		(19	)		11			(30	)		34			8			(19	)
Settlements		(4	)		1			(6	)		12			(5	)		6
Ending balance	$	86		$	152		$	86		$	152		$	59		$	117

The gains and losses included in earnings in the Level 3 fair value category were classified in electric fuel and other energy-related purchases in Virginia Power’s Consolidated Statements of Income for the three and nine months ended September 30, 2018 and 2017. 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 nine~~ months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~2018.

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, 2018
Assets
Interest rate	$	—	$	8	$	—	$	8
Foreign currency		—		32		—		32
Total assets	$	—	$	40	$	—	$	40
Liabilities
Commodity	$	—	$	9	$	—	$	9
Interest rate		—		1		—		1
Foreign currency		—		3		—		3
Total liabilities	$	—	$	13	$	—	$	13
At December 31, 2017
At March 31, 2019
Assets
Foreign currency	$	—	$	32	$	—	$	32	$	—	$	13	$	—	$	13
Total assets	$	—	$	32	$	—	$	32	$	—	$	13	$	—	$	13
Liabilities
Interest rate									$	—	$	41	$	—	$	41
Foreign currency										—		1		—		1
Total liabilities									$	—	$	42	$	—	$	42
At December 31, 2018
Assets
Commodity	$	—	$	4	$	2	$	6	$	—	$	3	$	—	$	3
Foreign currency		—		2		—		2		—		26		—		26
Total assets									$	—	$	29	$	—	$	29
Liabilities
Interest rate									$	—	$	17	$	—	$	17
Foreign currency										—		2		—		2
Total liabilities	$	—	$	6	$	2	$	8	$	—	$	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 no 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 months ended ~~September 30, 2018 and 2017.~~March 31, 2019.

	Nine Months Ended						Three Months Ended
	September 30,						March 31,
	2018			2017			2018
(millions)
Beginning balance	$	(2	)	$	(2	)	$	(2	)
Total realized and unrealized gains (losses):
Included in other comprehensive income (loss)		1			(1	)
Total realized and unrealized gains:
Included in other comprehensive income								1
Transfers out of Level 3		1			3			1
Ending balance	$	—		$	—		$	—

There were no gains or losses included in earnings in the Level 3 fair value category for the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~2018. 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 ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~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, 2018				December 31, 2017				March 31, 2019				December 31, 2018
	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⁾	$	30,401	$	31,488	$	28,666	$	31,233	$	35,123	$	37,531	$	29,952	$	31,045
Credit facility borrowings										—		—		73		73
Junior subordinated notes⁽³⁾		3,431		3,432		3,981		4,102		3,431		3,471		3,430		3,358
Remarketable subordinated notes⁽³⁾		1,384		1,324		1,379		1,446		1,387		1,398		1,386		1,340
Credit facility borrowings		73		73		—		—
Virginia Power
Long-term debt, including securities due within one year⁽³⁾	$	11,092	$	11,759	$	11,346	$	12,842	$	11,680	$	12,782	$	11,671	$	12,400
Dominion Energy Gas
Long-term debt, including securities due within one year⁽⁴⁾	$	4,061	$	4,061	$	3,570	$	3,719	$	4,058	$	4,155	$	4,058	$	4,072

(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 with short-term maturities and variable rates refinanced at current market rates is a reasonable estimate of their fair value.

(2)

Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium, and foreign currency remeasurement adjustments. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, includes the valuation of certain fair value hedges associated with fixed rate debt of ~~$(65)~~$(11) million and ~~$(22)~~$(20) million, respectively.

(3)	Carrying amount includes amounts which represent the unamortized debt issuance costs, discount or premium.

(4)	Carrying amount includes 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018. 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 1718 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, ~~before~~if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and ~~after the effects of offsetting:~~cash collateral received or paid:

															March 31, 2019									December 31, 2018
	September 30, 2018						December 31, 2017								Gross Amounts Not Offset in the Consolidated Balance Sheet										Gross Amounts Not Offset in the Consolidated Balance Sheet
	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Gross Assets Presented in the Consolidated Balance Sheet⁽¹⁾			Financial Instruments		Cash Collateral Received		Net Amounts		Gross Assets Presented in the Consolidated Balance Sheet⁽¹⁾			Financial Instruments		Cash Collateral Received		Net Amounts
(millions)
Commodity contracts:
Over-the-counter	$	109	$	—	$	109	$	174	$	—	$	174	$	77		$	5	$	—	$	72	$	175		$	12	$	—	$	163
Exchange		29		—		29		80		—		80		78			26		—		52		68			68		—		—
Interest rate contracts:
Over-the-counter		117		—		117		17		—		17		3			—		—		3		18			1		—		17
Foreign currency contracts:
Over-the-counter		32		—		32		32		—		32		13			7		—		6		26			2		—		24
Total derivatives, subject to a master netting or similar arrangement		287		—		287		303		—		303	$	171		$	38	$	—	$	133	$	287		$	83	$	—	$	204
Total derivatives, not subject to a master netting or similar arrangement		10		—		10		4		—		4
Total	$	297	$	—	$	297	$	307	$	—	$	307

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

			September 30, 2018									December 31, 2017									March 31, 2019									December 31, 2018
			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
	Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments		Cash Collateral Received		Net Amounts		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments		Cash Collateral Received		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	$	109		$	10	$	—	$	99	$	174		$	9	$	—	$	165	$	19		$	5	$	1	$	13	$	19	$	12	$	—	$	7
Exchange		29			29		—		—		80			80		—		—		26			26		—		—		115		68		47		—
Interest rate contracts:
Over-the-counter		117			9		—		108		17			8		—		9		323			6		—		317		142		1		—		141
Foreign currency contracts:
Over-the-counter		32			3		—		29		32			2		—		30		1			1		—		—		2		2		—		—
Total	$	287		$	51	$	—	$	236	$	303		$	99	$	—	$	204
Total derivatives, subject to a master netting or similar arrangement																			$	369		$	38	$	1	$	330	$	278	$	83	$	47	$	148

(1)	Excludes $— million and $1 million of derivative liabilities at March 31, 2019 and December 31, 2018, respectively, which are not subject to master netting or similar arrangements.

September 30, 2018

December 31, 2017

Gross
Amounts of
Recognized
Liabilities

Gross
Amounts
Offset in the
Consolidated
Balance Sheet

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

Gross
Amounts of
Recognized
Liabilities

Gross
Amounts
Offset in the
Consolidated
Balance Sheet

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

(millions)

Commodity contracts:

Over-the-counter

$
32

$
—

$
32

$
76

$
—

$
76

Exchange

68

—

68

120

—

120

Interest rate contracts:

Over-the-counter

42

—

42

85

—

85

Foreign currency contracts:

Over-the-counter

3

—

3

2

—

2

Total derivatives, subject to a master netting or
similar arrangement

145

—

145

283

—

283

Total derivatives, not subject to a master netting or
similar arrangement

—

—

—

1

—

1

Total

$
145

$
—

$
145

$
284

$
—

$
284

September 30, 2018

December 31, 2017

Gross Amounts Not
Offset in the
Consolidated
Balance Sheet

Gross Amounts Not
Offset in the
Consolidated
Balance Sheet

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Paid

Net
Amounts

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Paid

Net
Amounts

(millions)

Commodity contracts:

Over-the-counter

$
32

$
10

$
—

$
22

$
76

$
9

$
6

$
61

Exchange

68

29

39

—

120

80

40

—

Interest rate contracts:

Over-the-counter

42

9

—

33

85

8

—

77

Foreign currency contracts:

��

Over-the-counter

3

3

—

—

2

2

—

—

Total

$
145

$
51

$
39

$
55

$
283

$
99

$
46

$
138

Volumes

The following table presents the volume of Dominion Energy’s derivative activity at ~~September 30, 2018.~~March 31, 2019. 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⁾		71		29		78		61
Basis		261		607		277		547
Electricity (MWh):
Fixed price⁽¹⁾		9,770,320		957,820		7,915,870		1,100,600
FTRs		74,350,989		—		18,146,928		—
Liquids (Gal)⁽²⁾		35,084,400		—
NGLs (Gal)						25,074,000		—
Interest rate⁽³⁾⁽²⁾	$	600,000,000	$	5,023,819,541	$	2,554,400,000	$	5,001,010,256
Foreign currency⁽⁴⁾⁽³⁾	$	—	$	280,000,000	$	—	$	280,000,000

(1)	Includes options.

(2)	~~Includes NGLs and oil.~~

~~(3)~~

Maturity is determined based on final settlement period.

~~(4)~~(3)

Euro equivalent volumes are €250,000,000.

~~Ineffectiveness and~~ AOCI

For the three and nine months ended September 30, 2018 and 2017, gains or losses on hedging instruments determined to be ineffective and amounts excluded from the assessment of effectiveness were not material. Amounts excluded from the assessment of effectiveness include changes in the differences between spot prices and forward prices.

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 30, 2018:~~March 31, 2019:

	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	$	2		$	2		37 months	$	2		$	1		43 months
Electricity		(34	)		(34	)	15 months		33			24		21 months
Other		(7	)		(7	)	6 months
Interest rate		(219	)		(29	)	375 months		(333	)		(31	)	393 months
Foreign currency		13			(3	)	93 months		8			(1	)	87 months
Total	$	(245	)	$	(71	)		$	(290	)	$	(7	)

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.

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. Gains and losses on derivatives in fair value hedge relationships were immaterial for the three months ended March 31, 2019 and 2018.

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)						Cumulative Amount of Fair Value Hedging Adjustments Included in the Carrying Amount of the Hedged Assets(Liabilities)
	March 31, 2019			December 31, 2018			March 31, 2019		December 31, 2018
(millions)
Long-term debt	$	(739	)	$	(731	)	$	11	$	19

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, 2018
March 31, 2019
ASSETS
Current Assets
Commodity	$	8	$	86	$	94	$	35	$	59	$	94
Interest rate		58		—		58		2		—		2
Total current derivative assets⁽¹⁾		66		86		152		37		59		96
Noncurrent Assets
Commodity		3		51		54		15		48		63
Interest rate		59		—		59		1		—		1
Foreign currency		32		—		32		13		—		13
Total noncurrent derivative assets⁽²⁾		94		51		145		29		48		77
Total derivative assets	$	160	$	137	$	297	$	66	$	107	$	173
LIABILITIES
Current Liabilities
Commodity	$	64	$	32	$	96	$	17	$	21	$	38
Interest rate		10		—		10		79		1		80
Foreign currency		3		—		3		1		—		1
Total current derivative liabilities⁽³⁾		77		32		109		97		22		119
Noncurrent Liabilities
Commodity		3		1		4		1		6		7
Interest rate		32		—		32		230		13		243
Total noncurrent derivative liabilities⁽⁴⁾		35		1		36		231		19		250
Total derivative liabilities	$	112	$	33	$	145	$	328	$	41	$	369
December 31, 2017
December 31, 2018
ASSETS
Current Assets
Commodity	$	5	$	158	$	163	$	55	$	154	$	209
Interest rate		6		—		6		14		—		14
Total current derivative assets⁽¹⁾		11		158		169		69		154		223
Noncurrent Assets
Commodity		—		95		95		6		35		41
Interest rate		11		—		11		4		—		4
Foreign currency		32		—		32		26		—		26
Total noncurrent derivative assets⁽²⁾		43		95		138		36		35		71
Total derivative assets	$	54	$	253	$	307	$	105	$	189	$	294
LIABILITIES
Current Liabilities
Commodity	$	103	$	92	$	195	$	17	$	112	$	129
Interest rate		53		—		53		26		—		26
Foreign currency		2		—		2		2		—		2
Total current derivative liabilities⁽³⁾		158		92		250		45		112		157
Noncurrent Liabilities
Commodity		1		1		2		5		1		6
Interest rate		32		—		32		116		—		116
Total noncurrent derivative liabilities⁽⁴⁾		33		1		34		121		1		122
Total derivative liabilities	$	191	$	93	$	284	$	166	$	113	$	279

(1)	Current derivative assets are presented in other current assets 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 are presented in other current liabilities 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:~~Income.

Derivatives in cash flow hedging relationships	Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)⁽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, 2018
Three Months Ended March 31, 2019
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	(26	)							$	54
Purchased gas														3
Total commodity	$	(58	)	$	(26	)	$	—		$	66		$	57		$	—
Interest rate⁽³⁾		23			(12	)		48			(84	)		(10	)		(84	)
Foreign currency⁽⁴⁾		(1	)		(2	)		—			(11	)		(6	)		—
Total	$	(36	)	$	(40	)	$	48		$	(29	)	$	41		$	(84	)
Three Months Ended September 30, 2017
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	32
Electric fuel and other energy-related purchases					(1	)
Total commodity	$	8		$	31		$	—
Interest rate⁽³⁾		(4	)		(16	)		(26	)
Foreign currency⁽⁴⁾		12			10			—
Total	$	16		$	25		$	(26	)
Nine Months Ended September 30, 2018
Three Months Ended March 31, 2018
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	(55	)							$	(12	)
Purchased gas					(2	)								(2	)
Electric fuel and other energy-related purchases					8									7
Total commodity	$	(1	)	$	(49	)	$	—		$	97		$	(7	)	$	—
Interest rate⁽³⁾		70			(36	)		141			38			(12	)		68
Foreign currency⁽⁴⁾		(1	)		(10	)		—			13			8			—
Total	$	68		$	(95	)	$	141		$	148		$	(11	)	$	68
Nine Months Ended September 30, 2017
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	114
Electric fuel and other energy-related purchases					1
Total commodity	$	139		$	115		$	—
Interest rate⁽³⁾		(18	)		(39	)		(60	)
Foreign currency⁽⁴⁾		10			15			—
Total	$	131		$	91		$	(60	)

(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.

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
	September 30,						September 30,						March 31,
	2018			2017			2018			2017			2019			2018
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	(5	)	$	7		$	(8	)	$	22		$	3		$	6
Purchased gas		1			(6	)		5			2			3			—
Electric fuel and other energy-related purchases		(7	)		(19	)		(23	)		(51	)		(9	)		(13	)
Other operations & maintenance		—			1			—			(1	)
Total	$	(11	)	$	(17	)	$	(26	)	$	(28	)	$	(3	)	$	(7	)

(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.

Virginia Power

Balance Sheet Presentation

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

															March 31, 2019								December 31, 2018
	September 30, 2018						December 31, 2017								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Gross Assets Presented in the Consolidated Balance Sheet⁽¹⁾		Financial Instruments		Cash Collateral Received		Net Amounts		Gross Assets Presented in the Consolidated Balance Sheet⁽¹⁾		Financial Instruments		Cash Collateral Received		Net Amounts
(millions)
Commodity contracts:
Over-the-counter	$	89	$	—	$	89	$	155	$	—	$	155	$	61	$	2	$	—	$	59	$	64	$	6	$	—	$	58
Interest rate contracts:
Over-the-counter		65		—		65		—		—		—		—		—		—		—		3		—		—		3
Total derivatives, subject to a master netting or similar arrangement		154		—		154		155		—		155	$	61	$	2	$	—	$	59	$	67	$	6	$	—	$	61
Total derivatives, not subject to a master netting or similar arrangement		16		—		16		11		—		11
Total	$	170	$	—	$	170	$	166	$	—	$	166

September 30, 2018

December 31, 2017

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Net Amounts of Assets Presented
in the
Consolidated
Balance Sheet

Financial Instruments

Cash
Collateral
Received

Net
Amounts

Net Amounts of
Assets Presented
in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Received

Net
Amounts

(millions)

Commodity contracts:

Over-the-counter

$
89

$
5

$
—

$
84

$
155

$
4

$
—

$
151

Interest rate contracts:

Over-the-counter

65

—

—

65

—

—

—

—

Total

$
154

$
5

$
—

$
149

$
155

$
4

$
—

$
151

(1)	Excludes $5 million and $26 million of derivative assets at March 31, 2019 and December 31, 2018, respectively, which are not subject to master netting or similar arrangements.

			March 31, 2019								December 31, 2018
			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
(millions)
Commodity contracts:
Over-the-counter	$	3	$	2	$	1	$	—	$	6	$	6	$	—	$	—
Interest rate contracts:
Over-the-counter		181		—		—		181		88		—		—		88
Total derivatives, subject to a master netting or similar arrangement	$	184	$	2	$	1	$	181	$	94	$	6	$	—	$	88

(1)	Excludes $6 million and $9 million of derivative liabilities at March 31, 2019 and December 31, 2018, respectively, which are not subject to master netting or similar arrangements.

September 30, 2018

December 31, 2017

Gross
Amounts of
Recognized
Liabilities

Gross
Amounts
Offset in the
Consolidated
Balance Sheet

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

Gross
Amounts of
Recognized
Liabilities

Gross
Amounts
Offset in the
Consolidated
Balance Sheet

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

(millions)

Commodity contracts:

Over-the-counter

$
5

$
—

$
5

$
4

$
—

$
4

Interest rate contracts:

Over-the-counter

—

—

—

57

—

57

Total derivatives, subject to a master netting or
similar arrangement

5

—

5

61

—

61

Total derivatives, not subject to a master netting or
similar arrangement

3

—

3

5

—

5

Total

$
8

$
—

$
8

$
66

$
—

$
66

September 30, 2018

December 31, 2017

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Net Amounts of
Liabilities
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Paid

Net
Amounts

Net Amounts of
Liabilities
Presented in the Consolidated Balance Sheet

Financial
Instruments

Cash
Collateral
Paid

Net
Amounts

(millions)

Commodity contracts:

Over-the-counter

$
5

$
5

$
—

$
—

$
4

$
4

$
—

$
—

Interest rate contracts:

Over-the-counter

—

—

—

—

57

—

—

57

Total

$
5

$
5

$
—

$
—

$
61

$
4

$
—

$
57

Volumes

The following table presents the volume of Virginia Power’s derivative activity at ~~September 30, 2018.~~March 31, 2019. 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⁾		24		4		20		26
Basis		161		521		182		473
Electricity (MWh):
Fixed price⁽¹⁾		660,190		—
FTRs		73,336,004		—		18,146,928		—
Interest rate⁽²⁾	$	600,000,000	$	1,000,000,000	$	850,000,000	$	1,200,000,000

(1)	Includes options.

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

~~Ineffectiveness and~~ AOCI

~~For the three and nine months ended September 30, 2018 and 2017, gains or losses on hedging instruments determined to be ineffective were not material.~~

The following table presents selected information related to losses on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at ~~September 30, 2018:~~March 31, 2019:

	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	$	(5	)	$	(1	)	375 months	$	(20	)	$	(1	)	393 months
Total	$	(5	)	$	(1	)		$	(20	)	$	(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, 2018
ASSETS
Current Assets
Commodity	$	—	$	60	$	60
Interest rate		28		—		28
Total current derivative assets⁽¹⁾		28		60		88
Noncurrent Assets
Commodity		—		45		45
Interest rate		37		—		37
Total noncurrent derivative assets⁽²⁾		37		45		82
Total derivative assets	$	65	$	105	$	170
LIABILITIES
Current Liabilities
Commodity	$	—	$	8	$	8
Total current derivative liabilities⁽³⁾		—		8		8
Total derivative liabilities	$	—	$	8	$	8
December 31, 2017
March 31, 2019
ASSETS
Current Assets
Commodity	$	—	$	75	$	75	$	—	$	24	$	24
Total current derivative assets⁽¹⁾		—		75		75		—		24		24
Noncurrent Assets
Commodity		—		91		91		—		42		42
Total noncurrent derivative assets⁽²⁾		—		91		91		—		42		42
Total derivative assets	$	—	$	166	$	166	$	—	$	66	$	66
LIABILITIES
Current Liabilities
Commodity	$	—	$	9	$	9	$	—	$	6	$	6
Interest rate		44		—		44		44		—		44
Total current derivative liabilities⁽³⁾		44		9		53		44		6		50
Noncurrent Liabilities
Commodity								—	3			3
Interest rate		13		—		13		137		—		137
Total noncurrent derivatives liabilities ⁽⁴⁾		13		—		13		137		3		140
Total derivative liabilities	$	57	$	9	$	66	$	181	$	9	$	190
December 31, 2018
ASSETS
Current Assets
Commodity							$	—	$	60	$	60
Interest rate								3		—		3
Total current derivative assets⁽¹⁾								3		60		63
Noncurrent Assets
Commodity								—		30		30
Total noncurrent derivative assets⁽²⁾								—		30		30
Total derivative assets							$	3	$	90	$	93
LIABILITIES
Current Liabilities
Commodity							$	—	$	15	$	15
Interest rate								10		—		10
Total current derivative liabilities⁽³⁾								10		15		25
Noncurrent Liabilities
Interest rate								78		—		78
Total noncurrent derivatives liabilities ⁽⁴⁾								78		—		78
Total derivative liabilities							$	88	$	15	$	103

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

(4)	Noncurrent derivative liabilities are presented in other deferred credits and other 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 (Effective Portion)⁽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, 2018
Three Months Ended March 31, 2019
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	4		$	—		$	48		$	(9	)	$	—	$	(84	)
Total	$	4		$	—		$	48		$	(9	)	$	—	$	(84	)
Three Months Ended September 30, 2017
Three Months Ended March 31, 2018
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(3	)	$	—		$	(26	)	$	7		$	—	$	68
Total	$	(3	)	$	—		$	(26	)	$	7		$	—	$	68
Nine Months Ended September 30, 2018
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	13		$	—		$	141
Total	$	13		$	—		$	141
Nine Months Ended September 30, 2017
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(8	)	$	(1	)	$	(60	)
Total	$	(8	)	$	(1	)	$	(60	)

(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
	September 30,						September 30,						March 31,
	2018			2017			2018			2017			2019			2018
(millions)
Derivative type and location of gains (losses):
Commodity⁽²⁾	$	(9	)	$	(18	)	$	(12	)	$	(42	)	$	(9	)	$	—
Total	$	(9	)	$	(18	)	$	(12	)	$	(42	)	$	(9	)	$	—

(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, ~~before~~if the gross amounts recognized in its Consolidated Balance Sheets were netted with derivative instruments and ~~after the effects of offsetting.~~cash collateral received or paid:

September 30, 2018

December 31, 2017

Gross
Amounts of Recognized
Assets

Gross
Amounts
Offset in the Consolidated Balance Sheet

Net Amounts of Assets
Presented in the Consolidated Balance Sheet

Gross Amounts of Recognized
Assets

Gross
Amounts
Offset in the Consolidated
Balance Sheet

Net Amounts of Assets
Presented in the Consolidated
Balance Sheet

(millions)

Interest rate contracts:

Over-the-counter

$
8

$
—

$
8

$
—

$
—

$
—

Foreign currency contracts:

Over-the-counter

32

—

32

32

—

32

Total derivatives, subject to a master netting or
similar arrangement

$
40

$
—

$
40

$
32

$
—

$
32

September 30, 2018

December 31, 2017

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Gross Amounts Not Offset
in the Consolidated
Balance Sheet

Net Amounts of Assets
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Received

Net
Amounts

Net Amounts of Assets
Presented in the
Consolidated
Balance Sheet

Financial
Instruments

Cash
Collateral
Received

Net
Amounts

(millions)

Interest rate contracts:

Over-the-counter

$
8

$
1

$
—

$
7

$
—

$
—

$
—

$
—

Foreign currency contracts:

Over-the-counter

32

3

—

29

32

2

—

30

Total

$
40

$
4

$
—

$
36

$
32

$
2

$
—

$
30

															March 31, 2019									December 31, 2018
	September 30, 2018						December 31, 2017								Gross Amounts Not Offset in the Consolidated Balance Sheet									Gross Amounts Not Offset in the Consolidated Balance Sheet
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Assets Presented in the Consolidated Balance Sheet			Financial Instruments		Cash Collateral Received		Net Amounts		Gross Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
(millions)
Commodity contracts:
Over-the-counter	$	9	$	—	$	9	$	6	$	—	$	6	$	—		$	—	$	—	$	—	$	3	$	—	$	—	$	3
Interest rate contracts:
Over-the-counter		1		—		1		—		—		—
Foreign currency contracts:
Over-the-counter		3		—		3		2		—		2		13			7		—		6		26		2		—		24
Total derivatives, subject to a master netting or similar arrangement	$	13	$	—	$	13	$	8	$	—	$	8	$	13		$	7	$	—	$	6	$	29	$	2	$	—	$	27

			September 30, 2018								December 31, 2017								March 31, 2019								December 31, 2018
			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
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of 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)
Commodity contracts
Over-the-counter	$	9	$	—	$	—	$	9	$	6	$	—	$	—	$	6
Interest rate contracts:
Over-the-counter		1		1		—		—		—		—		—		—	$	41	$	6	$	—	$	35	$	17	$	—	$	—	$	17
Foreign currency contracts:
Over-the-counter		3		3		—		—		2		2		—		—		1		1		—		—		2		2		—		—
Total	$	13	$	4	$	—	$	9	$	8	$	2	$	—	$	6
Total derivatives, subject to a master netting or similar arrangement																	$	42	$	7	$	—	$	35	$	19	$	2	$	—	$	17

Volumes

The following table presents the volume of Dominion Energy Gas’ derivative activity at ~~September 30, 2018.~~March 31, 2019. 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
NGLs (Gal)		29,708,400		—		25,074,000		—
Interest rate⁽¹⁾	$	—	$	1,050,000,000	$	300,000,000	$	1,000,000,000
Foreign currency⁽¹⁾⁽²⁾	$	—	$	280,000,000	$	—	$	280,000,000

(1)	Maturity is based on final settlement period.

(2)	Euro equivalent volumes are €250,000,000.

~~Ineffectiveness and~~ AOCI

~~For the three and nine months ended September 30, 2018 and 2017, gains or losses on hedging instruments determined to be ineffective were not material.~~

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 30, 2018:~~March 31, 2019:

	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	$	(7	)	$	(7	)	6 months
Interest rate		(22	)		(4	)	315 months	$	(56	)	$	(5	)	309 months
Foreign currency		13			(3	)	93 months		8			(1	)	87 months
Total	$	(16	)	$	(14	)		$	(48	)	$	(6	)

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, 2018
ASSETS
Noncurrent Assets
Interest rate	$	8	$	—	$	8
Foreign currency		32		—		32
Total noncurrent derivative assets⁽¹⁾		40		—		40
Total derivative assets	$	40	$	—	$	40
LIABILITIES
Current Liabilities
Commodity	$	9	$	—	$	9
Interest rate		1		—		1
Foreign currency		3		—		3
Total current derivative liabilities⁽²⁾		13		—		13
Total derivative liabilities	$	13	$	—	$	13
December 31, 2017
March 31, 2019
ASSETS
Noncurrent Assets
Foreign currency	$	32	$	—	$	32	$	13	$	—	$	13
Total noncurrent derivative assets⁽¹⁾		32		—		32		13		—		13
Total derivative assets	$	32	$	—	$	32	$	13	$	—	$	13
LIABILITIES
Current Liabilities
Commodity	$	6	$	—	$	6
Interest rate							$	18	$	—	$	18
Foreign currency		2		—		2		1		—		1
Total current derivative liabilities⁽²⁾		8		—		8		19		—		19
Noncurrent Liabilities
Interest rate								23		—		23
Total noncurrent derivative liabilities⁽³⁾								23		—		23
Total derivative liabilities	$	8	$	—	$	8	$	42	$	—	$	42
December 31, 2018
ASSETS
Current Assets
Commodity							$	3	$	—	$	3
Total current derivative assets⁽⁴⁾								3		—		3
Noncurrent Assets
Foreign currency								26		—		26
Total noncurrent derivative assets⁽¹⁾								26		—		26
Total derivative assets							$	29	$	—	$	29
LIABILITIES
Current Liabilities
Interest rate							$	9	$	—	$	9
Foreign currency								2		—		2
Total current derivative liabilities⁽²⁾								11		—		11
Noncurrent Liabilities
Interest rate								8		—		8
Total noncurrent derivative liabilities⁽³⁾								8		—		8
Total derivative liabilities							$	19	$	—	$	19

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

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

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

(4)	Current derivative assets are presented in other current assets 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 (Effective Portion)⁽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, 2018
Three Months Ended March 31, 2019
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(3	)				$	2
Total commodity	$	(5	)	$	(3	)	$	(1	)	$	2
Interest rate⁽²⁾		10			(2	)		(24	)		(1	)
Foreign currency⁽³⁾		(1	)		(2	)		(11	)		(6	)
Total	$	4		$	(7	)	$	(36	)	$	(5	)
Three Months Ended September 30, 2017
Three Months Ended March 31, 2018
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(2	)				$	(3	)
Total commodity	$	(10	)	$	(2	)	$	4		$	(3	)
Interest rate⁽²⁾		—			(1	)		—			(1	)
Foreign currency⁽³⁾		12			10			13			8
Total	$	2		$	7		$	17		$	4
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	)
Nine Months Ended September 30, 2017
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(4	)
Total commodity	$	(5	)	$	(4	)
Interest rate⁽²⁾		—			(3	)
Foreign currency⁽³⁾		10			15
Total	$	5		$	8

(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.

Note 10. Investments

Dominion Energy

Equity and Debt Securities

Rabbi Trust Securities

Equity and ~~debt~~fixed income securities and cash equivalents in Dominion Energy’s rabbi trusts and classified as trading totaled ~~$114~~$112 million and ~~$112~~$111 million at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

Decommissioning Trust Securities

Dominion Energy holds equity and ~~debt~~fixed income securities, insurance contracts and cash equivalents ~~and cost method investments~~ 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				Recorded Value
(millions)
September 30, 2018
March 31, 2019
Equity securities:⁽¹⁾
U.S.											$	1,747	$	2,002	$	(17	)		$	3,732
Fixed income securities:⁽²⁾
Corporate debt instruments												457		15		(2	)			470
Government securities												1,076		29		(4	)			1,101
Common/collective trust funds												72		—		—				72
Insurance contracts												199		—		—				199
Cash equivalents and other⁽³⁾												6		—		—				6
Total											$	3,557	$	2,046	$	(23	)	⁽⁴⁾	$	5,580
December 31, 2018
Equity securities:⁽¹⁾
U.S.	$	1,710	$	2,128	$	(10	)		$	3,828	$	1,741	$	1,640	$	(51	)		$	3,330
Fixed income securities:⁽²⁾
Corporate debt instruments		438		6		(7	)			437		435		5		(9	)			431
Government securities		1,079		10		(19	)			1,070		1,092		17		(12	)			1,097
Common/collective trust funds		82		—		—				82		76		—		—				76
Cash equivalents and other⁽³⁾		7		—		—				7		4		—		—				4
Total	$	3,316	$	2,144	$	(36	)	⁽⁴⁾	$	5,424	$	3,348	$	1,662	$	(72	)	⁽⁴⁾	$	4,938
December 31, 2017
Equity securities:⁽²⁾
U.S.	$	1,569	$	1,857	$	—			$	3,426
Fixed income securities:⁽²⁾
Corporate debt instruments		430		15		(1	)			444
Government securities		1,039		27		(5	)			1,061
Common/collective trust funds		60		—		—				60
Cost method investments		68		—		—				68
Cash equivalents and other⁽³⁾		34		—		—				34
Total	$	3,200	$	1,899	$	(6	)	⁽⁴⁾	$	5,093

(1)	~~Effective January 2018, unrealized~~Unrealized gains and losses on equity securities ~~including those previously classified as cost method investments,~~ are included in other income and the nuclear decommissioning trust regulatory ~~liability as discussed in Note 2.~~liability.

(2)	Unrealized gains and losses on ~~equity securities (for 2017) and~~ fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability ~~as discussed in Note 2~~.

(3)	Includes pending sales of securities of ~~$ — million and $5~~$4 million at ~~September 30, 2018 and December~~March 31, ~~2017, respectively.~~2019.

(4)	The fair value of securities in an unrealized loss position was ~~$1.1 billion~~$405 million and ~~$565~~$833 million at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

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

(millions)

Three Months Ended September 30, 2018

Nine Months Ended September 30, 2018

Net gains recognized during the period

$
243

$
267

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

(7
)

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

$
236

$
225

	Three Months Ended March 31,
(millions)	2019			2018
Net gains (losses) recognized during the period	$	414		$	(65	)
Less: Net gains recognized during the period on securities sold during the period		(19	)		(19	)
Unrealized gains (losses) recognized during the period on securities still held at March 31, 2019 and 2018⁽¹⁾	$	395		$	(84	)

(1)	Included in other income and the nuclear decommissioning trust regulatory ~~liability as discussed in Note 2.~~liability.

The fair value of Dominion Energy’s ~~debt~~fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at ~~September 30, 2018~~March 31, 2019 by contractual maturity is as follows:

	Amount		Amount
(millions)
Due in one year or less	$	199	$	187
Due after one year through five years		344		382
Due after five years through ten years		389		394
Due after ten years		657		680
Total	$	1,589	$	1,643

Presented below is selected information regarding Dominion Energy’s equity and ~~debt~~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 March 31,
	2018		2017		2018		2017		2019		2018
(millions)
Proceeds from sales	$	457	$	377	$	1,301	$	1,496	$	506	$	419
Realized gains⁽¹⁾		24		25		96		142		43		36
Realized losses⁽¹⁾		18		16		60		52		23		19

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

~~Dominion Energy recorded other-than-temporary~~Other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds ~~as follows:~~recognized in earnings for Dominion Energy were immaterial for the three months ended March 31, 2019 and 2018.

Three Months Ended September 30,

Nine Months Ended September 30,

2018

2017

2018

2017

(millions)

Total other-than-temporary impairment losses⁽¹⁾

$
8

$
7

$
25

$
33

Losses recorded to the nuclear decommissioning trust regulatory liability

—

(2
)

—

(13
)
Losses recognized in other comprehensive income (before taxes)

(8
)

(1
)

(25
)

(2
)
Net impairment losses recognized in earnings

$
—

$
4

$
—

$
18

~~(1)~~

~~Amounts include other-than-temporary impairment losses for debt securities of less than $1 million and $2 million for the three and nine months ended September 30, 2017, respectively.~~

Virginia Power

Virginia Power holds equity and ~~debt~~fixed income securities and cash equivalents ~~and cost method investments~~ 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				Recorded Value
(millions)
September 30, 2018
March 31, 2019
Equity securities:⁽¹⁾
U.S.	$	842	$	965	$	(6	)		$	1,801	$	871	$	922	$	(9	)		$	1,784
Fixed income securities:⁽²⁾
Corporate debt instruments		220		2		(4	)			218		227		7		(1	)			233
Government securities		509		4		(8	)			505		506		14		(1	)			519
Common/collective trust funds		48		—		—				48		48		—		—				48
Cash equivalents and other⁽³⁾		1		—		—				1		7		—		—				7
Total	$	1,620	$	971	$	(18	)	⁽⁴⁾	$	2,573	$	1,659	$	943	$	(11	)	⁽⁴⁾	$	2,591
December 31, 2017
December 31, 2018
Equity securities:⁽²⁾⁽¹⁾
U.S.	$	734	$	831	$	—			$	1,565	$	858	$	751	$	(24	)		$	1,585
Fixed income securities:⁽²⁾
Corporate debt instruments		216		8		—				224		224		2		(5	)			221
Government securities		482		13		(2	)			493		504		7		(5	)			506
Common/collective trust funds		27		—		—				27		51		—		—				51
Cost method investments		68		—		—				68
Cash equivalents and other⁽³⁾		22		—		—				22		6		—		—				6
Total	$	1,549	$	852	$	(2	)	⁽⁴⁾	$	2,399	$	1,643	$	760	$	(34	)	⁽⁴⁾	$	2,369

(1)	~~Effective January 2018, unrealized~~Unrealized gains and losses on equity securities ~~including those previously classified as cost method investments,~~ are included in other income and the nuclear decommissioning trust regulatory ~~liability as discussed in Note 2.~~liability.

(2)	Unrealized gains and losses on ~~equity securities (for 2017) and~~ fixed income securities are included in AOCI and the nuclear decommissioning trust regulatory liability ~~as discussed in Note 2~~.

(3)	Includes pending sales of securities of $1$7 million and $6 million at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

(4)	The fair value of securities in an unrealized loss position was ~~$539~~$178 million and ~~$234~~$404 million at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

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, 2018

Nine Months Ended September 30, 2018

(millions)

Net gains recognized during the period

$
106

$
118

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

(3
)

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

$
103

$
92

	Three Months Ended March 31,
(millions)	2019			2018
Net gains (losses) recognized during the period	$	186		$	(32	)
Less: Net gains recognized during the period on securities sold during the period		(1	)		(15	)
Unrealized gains (losses) recognized during the period on securities still held at March 31, 2019 and 2018⁽¹⁾	$	185		$	(47	)

(1)	Included in other income and the nuclear decommissioning trust regulatory ~~liability as discussed in Note 2.~~liability.

The fair value of Virginia Power’s ~~debt~~fixed income securities with readily determinable fair values held in nuclear decommissioning trust funds at ~~September 30, 2018~~March 31, 2019 by contractual maturity is as follows:

	Amount		Amount
(millions)
Due in one year or less	$	64	$	77
Due after one year through five years		139		145
Due after five years through ten years		221		219
Due after ten years		347		359
Total	$	771	$	800

Presented below is selected information regarding Virginia Power’s equity and ~~debt~~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 March 31,
	2018		2017		2018		2017		2019		2018
(millions)
Proceeds from sales	$	237	$	156	$	651	$	654	$	253	$	218
Realized gains⁽¹⁾		11		9		44		64		10		18
Realized losses⁽¹⁾		5		6		17		24		9		5

(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 ~~not material~~immaterial for the three ~~and nine~~ months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~2018.

Equity Method Investments

Dominion Energy

~~Blue Racer~~

In October 2018, Dominion Energy entered into an agreement to sell its 50% limited partnership interest in Blue Racer. The transaction is expected to close in the fourth quarter of 2018, subject to clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act and the satisfaction of customary closing conditions, for up-front cash consideration of $1.05 billion. As a result, Dominion Energy expects to recognize a gain of approximately $380 million ($230 million after-tax) in the fourth quarter of 2018. In addition, the agreement contains additional deferred consideration of $150 million, subject to increase for interest costs effective March 2019, payable upon the purchaser’s availability of cash. This will result in a gain when realizable. Also, the purchaser agreed to pay additional consideration contingent upon the achievement of certain financial performance milestones of Blue Racer from 2019 through 2021. Pursuant to the purchase agreement, the aggregate will not exceed $300 million, which represents a gain contingency, and, as a result, Dominion Energy will not recognize any additional gain unless such consideration is realizable.

Atlantic Coast Pipeline

In September 2014, Dominion Energy, along with Duke 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 of March 31, 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 three members plan to be customers of the pipeline under 20-year contracts. Atlantic Coast Pipeline is considered an equity method investment as 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 ~~$147~~$95 million and ~~$84~~$78 million during the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and $306 million and $286 million during the nine months ended September 30, 2018 and 2017,~~ respectively, to Atlantic Coast Pipeline. At ~~September 30, 2018,~~March 31, 2019, Dominion Energy had ~~$37~~$32 million of contributions payable to Atlantic Coast Pipeline included within other current liabilities in the Consolidated Balance Sheets.

DETI provides services to Atlantic Coast Pipeline which totaled ~~$50~~$31 million and ~~$32~~$46 million for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and $156 million and $93 million for the nine months ended September 30, 2018 and 2017,~~ respectively, included in operating revenue in Dominion Energy and Dominion Energy Gas’ Consolidated Statements of Income. Amounts receivable related to these services were ~~$15~~$11 million and ~~$12~~$13 million at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~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 1617 for more information.

During the third and fourth quarters of 2018, a FERC stop work order together with delays in obtaining permits necessary for construction along with construction delays due to judicial actions impacted the cost and schedule for the project. As a result project cost estimates have increased from between $6.0 billion to $6.5 billion to between $7.0 billion to $7.5 billion, excluding financing costs. Atlantic Coast Pipeline expects to achieve a late 2020 in-service date for at least key segments of the project, while the

remainder may extend into early 2021. Alternatively, if it takes longer to resolve the judicial issues, such as through appeal to the Supreme Court of the U.S., full in-service could extend to the end of 2021 with total project cost estimated to increase an additional $250 million, resulting in total project cost estimates of $7.25 billion to $7.75 billion excluding financing costs. Abnormal weather, work delays (including due to judicial or regulatory action) and other conditions may result in further cost or schedule modifications in the future, which could result in a material impact to Dominion Energy’s cash flows, financial position and/or results of operations.

~~NedPower~~

~~At December 31, 2017,~~Blue Racer

In the first quarter of 2019, Dominion Energy ~~had a liability~~received $151 million of $17 million recorded to other deferred credits and other liabilities on the Consolidated Balance Sheets relating to its commitment to provide further financial support for NedPower. At September 30, 2018, Dominion Energy had no remaining liability.

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

~~In September 2018, Dominion Energy completed~~additional consideration, including applicable interest, in connection with the sale of ~~its 25%~~Dominion Energy’s 50% limited partnership interest in ~~Catalyst Old River Hydroelectric Limited Partnership and received proceeds of $91 million. The sale resulted~~Blue Racer in ~~a gain of $87 million ($63 million after-tax), which is included~~December 2018, as discussed in ~~other income~~Note 9 to the Consolidated Financial Statements in ~~Dominion Energy’s Consolidated Statement of Income.~~the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018.

Dominion Energy Gas

Iroquois

Dominion Energy Gas’ equity earnings totaled ~~$18~~$6 million and ~~$15~~$9 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017,~~ respectively. Dominion Energy Gas received distributions of ~~$20 million and $17~~$7 million for each of the ~~nine~~three months ended ~~September 30, 2018~~March 31, 2019 and ~~2017, respectively.~~2018. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, the carrying amount of Dominion Energy Gas’ investment of ~~$93~~$90 million and ~~$95~~$91 million, respectively, exceeded its share of underlying equity in net assets by $8 million. The difference reflects equity method goodwill and is not being amortized.

Note 11. Property, Plant and Equipment

~~Dominion Energy~~

~~Sale of Certain Retail Energy Marketing Assets~~

In October 2017, Dominion Energy entered into an agreement to sell certain assets associated with its nonregulated retail energy marketing operations for total consideration of $143 million, subject to customary approvals and certain adjustments. In December 2017, the first phase of the agreement closed for $79 million. In October 2018, the second phase of the agreement closed for $63 million, which will result in the recognition of a $65 million ($49 million after-tax) benefit in the fourth quarter of 2018. Pursuant to the agreement, Dominion Energy entered into a commission agreement with the buyer upon the first closing in December 2017 under which the buyer will pay a commission in connection with the right to use Dominion Energy’s brand in marketing materials and other services over a ten-year term.

~~Sale of Certain Merchant Generation Facilities~~

In September 2018, Dominion Energy entered into an agreement to sell Fairless and Manchester for total consideration of $1.2 billion, subject to customary closing adjustments. The transaction is expected to close in the fourth quarter of 2018, subject to FERC and other approvals, and Dominion Energy expects to recognize a gain of approximately $210 million ($150 million after-tax). Upon the close of the transaction, Dominion Energy will have to assess whether it is more-likely-than-not that state tax incentives could be used to reduce tax expense associated with the sale of these facilities. It is possible that these incentives could reduce the tax expense of this sale by up to $50 million.

In the third quarter of 2018, Fairless and Manchester’s assets and liabilities to be disposed were classified as held for sale. The carrying amounts of the major classes of assets and liabilities classified as held for sale in Dominion Energy’s Consolidated Balance Sheet are as follows:

September 30, 2018

(millions)

Assets:

Current assets
$
37

Property, plant and equipment, net

940

Other assets

52

Total assets
$
1,029

Liabilities:

Current liabilities
$
8

Asset retirement obligation

1

Total liabilities
$
9

Virginia Power

Acquisition of Solar Projects

In ~~September 2017,~~February 2019, Virginia Power ~~entered into agreements to acquire two solar development projects in North Carolina. The first~~completed the acquisition ~~closed in October 2018 and is expected to commence commercial operations during the fourth quarter~~ of 2018, and cost approximately $140 million once constructed, including the initial acquisition cost. The second acquisition is expected to close prior to the project commencing commercial operations, which is expected by the end of 2019, and cost approximately $140 million once constructed, including the initial acquisition cost. The projects are expected to generate approximately 155 MW combined. Virginia Power anticipates claiming federal investment tax credits on these solar projects.

~~In June 2018, Virginia Power entered into an agreement to acquire~~ a solar development project in Virginia. The ~~acquisition is expected to close prior to the project commencing~~facility commenced commercial operations ~~which is expected~~ in ~~the first quarter~~April 2019, ~~and~~generating 20 MW, at a cost ~~approximately~~of $37 million, ~~once constructed,~~ including the initial acquisition cost. ~~The project is expected to generate approximately 20 MW.~~ Virginia Power anticipates claiming federal investment tax credits on this solar ~~project upon its completion.~~project.

In August 2018, Virginia Power entered into agreements to acquire two solar development projects in North Carolina and Virginia. The first acquisition is expected to close prior to the project commencing commercial operations, which is expected by the end of 2019, and cost approximately $120 million once constructed, including the initial acquisition cost. The second acquisition was completed in March 2019. The project is expected to ~~close prior to the project commencing~~commence commercial operations ~~which is expected~~ by the end of 2020 and cost approximately $130 million once constructed, including the initial acquisition cost. The projects are expected to generate approximately 155 MW combined. Virginia Power anticipates claiming federal investment tax credits on these solar projects.

~~Assignment of Tower Rental Portfolio~~

Virginia Power rents space on certain of its electric transmission towers to various wireless carriers for communications antennae and other equipment. In March 2017, Virginia Power sold its rental portfolio to Vertical Bridge Towers II, LLC for $91 million in cash. The proceeds are subject to Virginia Power's FERC-regulated tariff, under which it is required to return half of the proceeds to customers. Virginia Power recorded $2 million in operating revenue and $2 million in other income for the three months ended September 30, 2018 and 2017, respectively, and recorded $5 million in operating revenue and $10 million in other income for the nine months ended September 30, 2018 and 2017, respectively, with $30 million remaining to be recognized ratably through 2023.

Dominion Energy Gas

Assignment of Shale Development Rights

In December 2013, Dominion Energy Gas 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. As a result of this amendment, in the third quarter of 2017, Dominion Energy Gas recognized a $56 million ($33 million after-tax) gain included in other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income associated with the finalization of the contractual matters on previous conveyances. Additionally, in the fourth quarter of 2017, Dominion Energy recognized a $9 million ($5 million after-tax) gain included in other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income associated with the elimination of its overriding royalty interest. In September 2018, Dominion Energy Gas recognized a $65 million ($47 million after-tax) gain included in other operations and maintenance expense 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 to convey over time approximately 24,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields. In July 2017, in connection with the existing agreement, Dominion Energy Gas conveyed approximately 2,000 acres of Marcellus Shale development rights and received proceeds of $5 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $5 million ($3 million after-tax) gain included in other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income. In January 2018, Dominion Energy Gas and the 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 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 ~~other operations and maintenance expense~~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 one 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 ~~other operations and maintenance expense~~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 one 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 other operations and maintenance expense in Dominion Energy Gas’ Consolidated Statements of Income.

Note 12. Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	March 31, 2019		December 31, 2018
(millions)
Dominion Energy
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	117	$	174
Deferred rate adjustment clause costs for Virginia electric utility⁽²⁾⁽³⁾		90		78
Deferred nuclear refueling outage costs⁽⁴⁾		70		69
Unrecovered NND Project costs⁽⁵⁾		138		—
PJM transmission rates⁽⁶⁾		64		45
Other		246		130
Regulatory assets-current		725		496
Deferred cost of fuel used in electric generation⁽¹⁾		123		83
Unrecognized pension and other postretirement benefit costs⁽⁷⁾		1,521		1,497
Deferred rate adjustment clause costs for Virginia electric utility^(2)(3)(8)		194		230
Deferred project costs for gas utilities⁽⁹⁾		440		335
PJM transmission rates⁽⁶⁾		174		192
Interest rate hedges⁽¹⁰⁾		563		184
AROs and related funding⁽¹¹⁾		350		—
Cost of reacquired debt^(12)(13)		203		3
Unrecovered NND Project costs⁽⁵⁾		2,607		—
Ash pond and landfill closure costs⁽¹⁴⁾		935		27
Other		465		125
Regulatory assets-noncurrent		7,575		2,676
Total regulatory assets	$	8,300	$	3,172
Regulatory liabilities:
Provision for future cost of removal and AROs⁽¹⁵⁾	$	117	$	117
Reserve for refunds and rate credits to electric utility customers⁽¹⁶⁾		137		71
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁷⁾		93		104
Income taxes refundable through future rates⁽¹⁸⁾		127		—
Monetization of guarantee settlement⁽¹⁹⁾		67		—
Other		71		64
Regulatory liabilities-current		612		356
Income taxes refundable through future rates⁽¹⁸⁾		5,034		4,071
Provision for future cost of removal and AROs⁽¹⁵⁾		2,222		1,409
Nuclear decommissioning trust⁽²⁰⁾		1,247		1,070
Monetization of guarantee settlement⁽¹⁹⁾		1,020		—
Reserve for refunds and rate credits to electric utility customers⁽¹⁶⁾		846		—
Overrecovered other postretirement benefit costs⁽²¹⁾		129		120
Other		301		170
Regulatory liabilities-noncurrent		10,799		6,840
Total regulatory liabilities	$	11,411	$	7,196

September 30, 2018

December 31, 2017

(millions)

Dominion Energy

Regulatory assets:

Deferred cost of fuel used in electric generation⁽¹⁾

$
260

$
23

Deferred rate adjustment clause costs⁽²⁾

124

70

Deferred nuclear refueling outage costs⁽³⁾

58

54

Unrecovered gas costs⁽⁴⁾

3

38

Other

95

109

Regulatory assets-current

540

294

Unrecognized pension and other postretirement benefit costs⁽⁵⁾

1,276

1,336

Deferred rate adjustment clause costs⁽²⁾

312

401

PJM transmission rates⁽⁶⁾

265

222

Utility reform legislation⁽⁷⁾

189

147

Derivatives⁽⁸⁾

83

223

Other

191

151

Regulatory assets-noncurrent

2,316

2,480

Total regulatory assets

$
2,856

$
2,774

Regulatory liabilities:

Provision for future cost of removal and AROs⁽⁹⁾

$
101

$
101

Cost-of-service impact of 2017 Tax Reform Act⁽¹⁰⁾

80

—

Reserve for rate credits to electric utility customers⁽¹¹⁾

61

—

Other

93

92

Regulatory liabilities-current⁽¹²⁾

335

193

Income taxes refundable through future rates⁽¹³⁾

4,088

4,058

Provision for future cost of removal and AROs⁽⁹⁾

1,414

1,384

Nuclear decommissioning trust⁽¹⁴⁾

1,241

1,121

Other

403

353

Regulatory liabilities-noncurrent

7,146

6,916

Total regulatory liabilities

$
7,481

$
7,109

Virginia Power

Regulatory assets:

Deferred cost of fuel used in electric generation⁽¹⁾

$
260

$
23

Deferred rate adjustment clause costs⁽²⁾

101

56

Deferred nuclear refueling outage costs⁽³⁾

58

54

Other

60

72

Regulatory assets-current

479

205

Deferred rate adjustment clause costs⁽²⁾

225

312

PJM transmission rates⁽⁶⁾

265

222

Derivatives⁽⁸⁾

50

190

Other

96

86

Regulatory assets-noncurrent

636

810

Total regulatory assets

$
1,115

$
1,015

Regulatory liabilities:

Provision for future cost of removal⁽⁹⁾

$
80

$
80

Cost-of-service impact of 2017 Tax Reform Act⁽¹⁰⁾

67

—

Reserve for rate credits to customers⁽¹¹⁾

61

—

Other

42

47

Regulatory liabilities-current ⁽¹²⁾

250

127

Income taxes refundable through future rates⁽¹³⁾

2,561

2,581

Nuclear decommissioning trust⁽¹⁴⁾

1,241

1,121

Provision for future cost of removal⁽⁹⁾

938

915

Derivatives⁽⁸⁾

38

69

Other

112

74

Regulatory liabilities-noncurrent

4,890

4,760

Total regulatory liabilities

$
5,140

$
4,887

Dominion Energy Gas

Regulatory assets:

Deferred rate adjustment clause costs⁽²⁾

$
23

$
14

Unrecovered gas costs⁽⁴⁾

—

8

Other

2

4

Regulatory assets-current⁽¹⁵⁾

25

26

Unrecognized pension and other postretirement benefit costs⁽⁵⁾

248

258

Utility reform legislation⁽⁷⁾

189

147

Deferred rate adjustment clause costs⁽²⁾

87

89

Other

27

17

Regulatory assets-noncurrent⁽¹⁶⁾

551

511

Total regulatory assets

$
576

$
537

Regulatory liabilities:

Provision for future cost of removal and AROs⁽⁹⁾

$
13

$
13

Overrecovered gas costs⁽⁴⁾

6

—

PIPP⁽¹⁷⁾

4

20

Other

9

5

Regulatory liabilities-current⁽¹²⁾

32

38

Income taxes refundable through future rates⁽¹³⁾

1,038

998

Provision for future cost of removal and AROs⁽⁹⁾

164

160

Cost-of-service impact of 2017 Tax Reform Act⁽¹⁰⁾

15

—

Other

92

69

Regulatory liabilities-noncurrent

1,309

1,227

Total regulatory liabilities

$
1,341

$
1,265

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

(2)

~~Primarily reflects~~Reflects deferrals under ~~the~~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 and deferrals of costs associated with certain current and prospective rider projects for Dominion Energy Gas.~~Power. See Note 13 for more information.

(3)

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.

(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.

~~(4)~~(5)

Reflects ~~unrecovered or overrecovered gas costs at regulated gas operations, which are recovered or refunded through filings~~expenditures by DESC associated with the ~~applicable regulatory authority.~~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 for more information.

~~(5)~~(6)

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.

(7)

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 ~~and Dominion Energy Gas'~~ rate-regulated subsidiaries.

~~(6)~~(8)

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

(9)

Primarily reflects amounts ~~related~~expected to ~~the PJM transmission cost allocation matter.~~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.

~~(7)~~(10)

~~Ohio legislation under House Bill 95,~~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 became effective in September 2011. This law updates natural gas legislation by enabling gas companies to include more up-to-date cost levels when filing rate cases. It also allows gas companies to seek approvalhas a weighted average useful life of capital expenditure plans under which gas companies can recognize carrying costs on associated capital investments placed in service and can defer the carrying costs plus depreciation and property tax expenses for recovery from ratepayers in the future.approximately 30 years.

~~(8)~~(11)

~~For jurisdictions subject~~Represents deferred depreciation and accretion expense related to ~~cost-based rate regulation, changes in~~legal obligations associated with the ~~fair value~~future retirement of ~~derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they~~property, plant and equipment, excluding amounts related to CCRs, for DESC and PSNC. The AROs primarily relate to nuclear decommissioning activities and are expected to be recovered ~~from or refunded~~over the related property lives and periods of decommissioning which may range up to ~~customers.~~approximately 106 years.

~~(9)~~(12)

Cost 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 30 years as of March 31, 2019.

(13)

In March 2019, DESC purchased certain of its first mortgage bonds having an aggregate purchase price of $1.2 billion, as discussed in Note 16. As a result of this transaction, Dominion Energy incurred costs, including write-off of unamortized discount, premium, and debt issuance costs, of $187 million.

(14)	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. See Note 17 for additional information.

(15)	Rates charged to customers by ~~the Companies’~~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.

~~(10)~~(16)

Reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited over an estimated 11-year period 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. 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 in this report for more information.

(17)

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 in this report for more information.

(18)

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.

(19)	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 for additional information.

(20)

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.

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

	March 31, 2019		December 31, 2018
(millions)
Virginia Power
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	112	$	174
Deferred rate adjustment clause costs⁽²⁾⁽³⁾		90		78
Deferred nuclear refueling outage costs⁽⁴⁾		70		69
PJM transmission rates⁽⁵⁾		64		45
Other		51		58
Regulatory assets-current⁽⁶⁾		387		424
Deferred rate adjustment clause costs^(2)(3)(7)		194		230
PJM transmission rates⁽⁵⁾		174		192
Interest rate hedges⁽⁸⁾		235		151
Deferred cost of fuel used in electric generation⁽¹⁾		123		83
Ash pond and landfill closure costs⁽⁹⁾		935		27
Other		58		54
Regulatory assets-noncurrent		1,719		737
Total regulatory assets	$	2,106	$	1,161
Regulatory liabilities:
Provision for future cost of removal⁽¹⁰⁾	$	92	$	92
Cost-of-service impact of 2017 Tax Reform Act⁽¹¹⁾		88		95
Reserve for rate credits to electric utility customers⁽¹²⁾		—		71
Income taxes refundable through future rates⁽¹³⁾		74		—
Other		27		41
Regulatory liabilities-current		281		299
Income taxes refundable through future rates⁽¹³⁾		2,500		2,579
Nuclear decommissioning trust⁽¹⁴⁾		1,247		1,070
Provision for future cost of removal⁽¹⁰⁾		959		940
Other		102		58
Regulatory liabilities-noncurrent		4,808		4,647
Total regulatory liabilities	$	5,089	$	4,946

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

(2)	Primarily 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) 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.

(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) to write-off the balance of a regulatory asset for which it is no longer seeking recovery.

(8)	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 21 years.

(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. See Note 17 for additional information.

(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 in this report for more information.

(12)	Charge associated with Virginia legislation enacted in March 2018 that ~~requires~~required one-time rate credits of certain amounts to utility customers. See Note 13 ~~for more information.~~

~~(12)~~

~~Current regulatory liabilities are presented in other current liabilities~~to the Consolidated Financial Statements in the Companies’ ~~Consolidated Balance Sheets.~~Annual Report on Form 10-K for the year ended December 31, 2018 for more information.

(13)

(14)

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.

	March 31, 2019		December 31, 2018
(millions)
Dominion Energy Gas
Regulatory assets:
Deferred project costs⁽¹⁾	$	3	$	18
PIPP⁽²⁾		5		—
Unrecovered gas costs⁽³⁾		—		9
Other		3		2
Regulatory assets-current⁽⁴⁾		11		29
Unrecognized pension and other postretirement benefit costs⁽⁵⁾		389		392
Deferred project costs⁽¹⁾		366		334
Other		1		1
Regulatory assets-noncurrent⁽⁶⁾		756		727
Total regulatory assets	$	767	$	756
Regulatory liabilities:
Provision for future cost of removal and AROs⁽⁷⁾	$	14	$	14
PIPP⁽²⁾		—		3
Other		12		4
Regulatory liabilities-current⁽⁸⁾		26		21
Income taxes refundable through future rates⁽⁹⁾		1,002		1,011
Provision for future cost of removal and AROs⁽⁷⁾		161		158
Overrecovered other postretirement benefit costs⁽¹⁰⁾		98		92
Other		30		24
Regulatory liabilities-noncurrent		1,291		1,285
Total regulatory liabilities	$	1,317	$	1,306

(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.

~~(15)~~

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

~~(16)~~

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

~~(17)~~(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 ~~rate adjustment clause~~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 the applicable regulatory authority.

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

(5)	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.

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

(7)	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.

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

(9)

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

At ~~September 30, 2018, $447 million~~March 31, 2019, $1.5 billion of Dominion Energy's and ~~$364~~$295 million of Virginia Power's regulatory assets represented past expenditures on which they do not currently earn a return. With the exception of the ~~$265 million PJM transmission cost allocation matter,~~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 ~~for which~~that the Companies cannot estimate, ~~a range of possible loss,~~ 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 ~~for which~~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. ~~Virginia Power purchases and, under its FERC market-based rate authority, sells electricity in the wholesale market.~~ 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 ~~growing~~ investment in electric transmission infrastructure.

In March 2010, ~~Old Dominion Electric Cooperative~~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.

~~PJM Transmission Rates~~

In ~~April 2007,~~January 2019, FERC issued an order regarding its transmission rate design for the allocation of costs among PJM transmission customers, including Virginia Power, for transmission service provided by PJM. For new PJM-planned transmission facilities that operate at or above 500 kV, FERC established a PJM regional rate design where customers pay accordingdenying PJM’s request to ~~each customer’s share~~waive certain provisions of the region’s load. For recovery of costs of existing facilities, FERC approved the existing methodology whereby a customer pays the cost of facilities located in the same zone as the customer. A number of parties appealed the order to the U.S. Court of Appeals for the Seventh Circuit.

In August 2009, the court issued its decision affirming the FERC order with regard to the existing facilities, but remanded to FERC the issue of the cost allocation associated with the new facilities 500 kV and above for further consideration by FERC. On remand, FERC reaffirmed its earlier decision to allocate the costs of new facilities 500 kV and above according to the customer’s share of the region’s load. A number of parties filed appeals of the order to the U.S. Court of Appeals for the Seventh Circuit. In June 2014, the court again remanded the cost allocation issue to FERC. In December 2014, FERC issued an order setting an evidentiary hearing and settlement proceedingPJM Tariff regarding the ~~cost allocation issue. The hearing only concerns the costs~~liquidation of ~~new facilities approved~~a portfolio of FTRs owned by ~~PJM prior to February 1, 2013. Transmission facilities approved after February 1, 2013 are allocated~~GreenHat who had defaulted on ~~a hybrid cost allocation method approved by FERC and not subject to any court review.~~

In June 2016, PJM, the PJM transmission owners and state commissions representing substantially all of the load in the PJM market submitted a settlement to FERC to resolve the outstanding issues regarding this matter. In May 2018, FERC issued an order accepting the settlement agreement and directed PJM to make a compliance filing with revised tariff records.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 ~~August 2018,~~February 2019, Virginia Power ~~began~~and certain other PJM members filed a request for rehearing with FERC. While the impacts of this order could be material to make payments to PJM, to continue for the next 10 years totaling $276 million, under the terms of revised tariff records, which is partially offset by a $265 million regulatory asset for the amount that will be recovered through retail rates in Virginia. At September 30, 2018, Virginia Power’s ~~Consolidated Balance Sheet includes $170 million included~~results of operations, financial condition and/or cash flows, the existing regulatory framework in ~~other current liabilities and $72 million included in other deferred credits and other liabilities.~~Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts.

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’s~~Energy and Dominion Energy Gas’ results of operations. In December 2017, DETI provided its response to the audit report. DETI ~~requested~~reached resolution of certain matters with FERC ~~review of contested findings and submitted its plan for compliance with~~in the uncontested portions of the report. In connection with one uncontested issue, DETI recognized a charge of $15 million ($9 million after-tax) recorded within other operations and maintenance expense in Dominion Energy’s and Dominion Energy Gas’ Consolidated Statements of Income during the secondfourth quarter of 2017 to write-off the balance of a regulatory asset, originally established in 2008, that is no longer considered probable of recovery. DETI recognized a charge of $129 million ($94 million after-tax) recorded primarily within other operations and maintenance expense 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.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

~~Subsequent~~Other than the items discussed below, which are pending or have been resolved during the period, there have been no changes to ~~the enactment of~~ the 2017 Tax Reform Act matters discussed in Notes 3 and 13 to the Consolidated Financial Statements in the Companies’ ~~state regulators issued orders requesting that public utilities evaluate~~Annual Report on Form 10-K for the ~~total tax impact on the entity’s cost of service and accrue a regulatory liability attributable to the benefits of the reduction~~year ended December 31, 2018.

In January 2019, Virginia Power filed updated testimony in ~~the corporate income tax rate. Certain of the orders requested that the public utilities submit a~~ response to the ~~state regulatory commissions detailing the total tax impact on the utility’s cost of service.~~

The Companies began to reserve the impacts of the cost-of-service reduction as regulatory liabilities in January 2018 and will continue until rates are reset pursuant to state regulators’ approvals. The Companies have recorded a reasonable estimate of net income taxes refundable through future rates in the jurisdictions in which they operate and are currently assessing these actions and decisions, which could have a material impact on the Companies’ results of operations, financial condition and/or cash flows.

InVirginia Commission’s September 2018 ~~the Virginia Commission issued an~~ order ~~directing Virginia Power to submit~~with a filing quantifying the impacts of the 2017 Tax Reform Act in advance of the April 1, 2019 implementation as required by legislation. In October 2018, Virginia Power filed an application with the Virginia Commission to implement final adjustments in its base rates reflecting actual annual reductions in corporate income taxes resulting from the 2017 Tax Reform Act. The proposed annual revenue reduction isof approximately ~~$151 million effective April 2019.~~$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. ~~Based on~~In March 2019, the Virginia ~~Power’s proposed~~Commission issued an order approving an annual revenue reduction ~~this~~of approximately $183 million effective April 2019 and ordering Virginia Power to implement the one-time ~~bill~~customer credit, is estimated to total approximately ~~$95 million. The actual credit will be based~~$135 million, on ~~actual billing data and customer usage during that 15-month period. This matter is pending.~~

In August 2018, Virginia Power filed with FERC to waive protocols and begin reflecting projected tax reform benefits of approximately $100 million through the transmission formula rate prior to the normal formula rate process. FERC granted the waiver and the amounts will begin being reflected in customer billings in November 2018 and subsequently reflecting the adjustment effective Januaryor before July 1, ~~2018.~~2019.

In October 2018, the North Carolina ~~Utilities~~ 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, which is estimated to be approximately $13 million. 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. ~~This matter is pending.~~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 ~~May 2018,~~March 2019, Questar Gas filed with the Utah Commission approved a stipulation submitted by Questar Gas proposing the cost-of-service component of customer rates be reduced by $15 million annually beginning in June 2018. In July 2018, the Utah Commission approved Questar Gas’ request to return an additional $9 million to Utah customers representing the amounts relatedand Wyoming Commissions as to the corporate income tax reduction that had been deferred from January 1, 2018 to May 31, 2018. This additional reduction began amortizing on August 1, 2018 and will be amortized over a one-year period. In October 2018, the Wyoming Commission approved Questar Gas’ request to return deferred amounts through a surcredit beginning November 1, 2018. The surcredit will remain in effect until rates become effective in the next Wyoming general rate case. The impact of excess deferred income taxes resulting from the 2017 Tax Reform ~~Act on rates charged~~Act. Questar Gas proposed to return the 2018 amortization of excess deferred income taxes to customers ~~will be reported~~and to incorporate the ~~Utah and Wyoming Commissions by the first quarter of 2019.~~remaining excess deferred income tax impact in its next general rate cases in each jurisdiction. This matter is pending.

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 ~~currently evaluating this order and plans to file an application in the fourth quarter of 2018.~~pending.

As directed by the Public Service Commission of West Virginia, Hope is utilizing regulatory accounting to track the effects of the 2017 Tax Reform Act beginning in January 2018 and submitted testimony in July 2018 detailing such effects. In August 2018, the Public Service Commission of West Virginia approved a settlement implementing base rate reductions effective September 1, 2018. These reductions are not expected to have a material impact on Hope’s financial condition.

In March 2018, FERC announced actions to address the income tax allowance component of regulated entities’ cost-of-service rates as a result of the 2017 Tax Reform Act. FERC issued a notice of proposed rulemaking introducing a process for determining whether jurisdictional natural gas pipelines may be collecting unjust and unreasonable rates as a result of the reduction in the corporate income tax rate. The proposed rule would requirerequired all interstate natural gas pipelines 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 the impacts of the changes in tax law. The actions also included the reversal of FERC’s policy allowing master limited partnerships to recover an income tax allowance in cost-of-service rates and requiring other pass-through entities to justify the inclusion of an income tax allowance. FERC also issued a notice of inquiry seeking comments on whether it should take any additional actions to address changes in federal corporate income taxes, the elimination of an income tax allowance for master limited partnerships, excess or deficient accumulated deferred income taxes and bonus depreciation, among other items.

In July 2018, FERC issued a final rule adopting and modifying the procedures for determining whether jurisdictional natural gas pipelines may be collecting unjust and unreasonable rates in light of the reduction in the corporate income tax rate. These procedures are generally the same as the proposals issued in March; however the final rule modifies the treatment of the income tax allowance for master limited partnerships and other pass-through entities in the informational filing. Specifically, this final rule does not require master limited partnerships to eliminate their income tax allowances when completing the informational filing, and allows entities that are wholly-owned by corporations to include an income tax allowance. Although the informational filing does not require the elimination of the income tax allowance for master limited partnerships, and provides options to master limited partnerships to address the income tax allowance that were previously unavailable including providing evidence that a double recovery of income taxes does

~~not exist, there can be no assurance that master limited partnerships would be allowed to include an income tax allowance in the future.~~

~~Beginning in October~~During 2018, Dominion ~~Energy and~~Energy’s FERC-regulated pipelines, including those accounted for as equity method investments, filed the Form 501-G with FERC. Dominion Energy ~~Gas have filed or expect to file the required informational reports with FERC indicating no changes to current rates charged to customers. Given the associated uncertainty,~~Overthrust Pipeline, LLC, White River Hub, Dominion Energy Questar Pipeline, DETI, DECG, Cove Point and ~~Dominion Energy Gas are currently unable to predict~~Iroquois have reached resolution through a FERC waiver or FERC terminating the ~~outcome of these matters; however, any change~~501-G proceeding, or through settlement, which did not result in ~~rates permitted to be charged to customers could have~~ a material impact onto results of operations, financial condition and/or cash ~~flows.~~flows of Dominion Energy or Dominion Energy Gas.

Other Regulatory Matters

Other than the following matters, there have been no significant developments regarding the pending regulatory matters disclosed in ~~Note~~Notes 3 and 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, and Note 13 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarters ended March 31, 2018 and June 30, 2018.

Virginia Regulation

~~Virginia Fuel Expenses~~Regulation Act

In ~~May 2018,~~March 2019, Virginia Power filed ~~its annual fuel factor with~~an application for the Virginia Commission to ~~recover an estimated $1.5 billion in Virginia jurisdictional projected fuel expenses~~determine the general ROE for ~~the rate year beginning July 1, 2018.~~ Virginia Power’s ~~proposed fuel~~non-transmission rate ~~represents a fuel revenue increase~~adjustment clauses and for purposes of ~~$222 million when applied to projected kilowatt-hour sales for the period July 1, 2018 to June 30, 2019. In August 2018, the Virginia Commission approved~~determining Virginia Power’s ~~fuel rate with an increase of $209 million.~~

~~Grid Transformation and Security Act of 2018~~

~~In March 2018, the Governor of Virginia signed into law legislation to reinstate~~ base rate ~~reviews on a triennial basis other than~~earnings in the ~~first review, which will be a~~2021 quadrennial review ~~occurring for Virginia Power in 2021~~ for the four successive 12-month test periods beginning January 1, 2017 and ending December 31, 2020. ~~This review~~The application supported a 10.75% ROE for ~~Virginia Power will occur one year earlier than under the Regulation Act legislation enacted in February 2015.~~

In the triennial review proceedings, earnings that are more than 70 basis points above the utility’s authorized return on equity that might have been refunded to customers may be reduced by approved investment amounts in qualifying solar or wind generation facilities or electric distribution grid transformation projects that Virginia Power elects to include in a customer credit reinvestment offset. The legislation declares that electric distribution grid transformation projects are in the public interest and provides that the costs of such projects may be recovered through athese rate adjustment clause if not the subject of a customer credit reinvestment offset. Any costs that are the subject of a customer credit reinvestment offset may not be recovered in base rates for the service life of the projectsclauses and ~~may not be included in base rates in future triennial~~quadrennial review ~~proceedings.~~period. This case is pending.

Solar Facility Projects

The legislation also includes provisions requiring Virginia Power to provide current customers one-time rate credits totaling $200 million and to reduce base rates to reflect reductions in income tax expense resulting from the 2017 Tax Reform Act. As a result, Virginia Power incurred a $215 million ($160 million after-tax) charge in connection with this legislation, including the impact on certain non-jurisdictional customers which follow Virginia Power’s jurisdictional customer rate methodology. In July 2018, Virginia Power ~~credited $138~~applied for approval of Rider US-3 associated with the Colonial Trail West and Spring Grove 1 solar projects with a proposed $10 million ~~to current customers’ bills.~~

~~In addition, Virginia Power will reduce base rates on an annual basis by $125 million effective July 2018, to reflect~~total revenue requirement for the ~~estimated effect of the 2017 Tax Reform Act, which is subject to adjustment in April~~rate year beginning March 1, 2019. In ~~May and~~April 2019, the Virginia Commission approved the revenue requirement for the rate year beginning June 2018, Virginia Power submitted filings detailing the implementation plan for interim reductions in rates for generation and distribution services pursuant to the Grid Transformation and Security Act of 2018.1, 2019.

Rate Adjustment Clauses

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

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 March 2019, Virginia Power requested approval of its fourth phase of conversions totaling $123 million. Virginia Power also proposed a total $52 million revenue requirement for the rate year beginning February 1, 2020 for continuing recovery of the previously approved phase conversions and the proposed fourth phase conversions. This matter is pending.

The Virginia Commission previously approved Riders C1A and C2A in connection with cost recovery for DSM programs. In October 2018, Virginia Power requested approval to implement ten new energy efficiency programs and one new demand-response DSM program for five years, subject to future extensions, with a $262 million cost cap, and proposed a total $49 million revenue requirement for the rate year beginning July 1, 2019, which represents an $18 million increase over the previous year. ~~This matter is pending.~~

•

The Virginia Commission previously approved Rider BW in conjunction with Brunswick County. In October 2018, Virginia Power proposed a $123 million revenue requirement for the rate year beginning September 1, 2019, which represents a $7 million increase over the previous year. This matter is pending.

The Virginia Commission previously approved Rider US-2 in conjunction with Scott Solar, Whitehouse, and Woodland. In October 2018, Virginia Power proposed a $16 million revenue requirement for the rate year beginning September 1, 2019, which represents a $3 million increase over the previous year. This matter is pending.

~~The Virginia Commission previously approved Rider T1 concerning transmission rates.~~ In May 2018, Virginia Power proposed a $755 million total revenue requirement consisting of $468 million for the transmission component of Virginia Power’s base rates and $287 million for Rider T1. This total revenue requirement represents a $146 million increase versus the revenues to be produced during the rate year under current rates. In August 2018,2019, the Virginia Commission approved a total revenue requirement of ~~$630~~$49 million, ~~including Rider T1,~~ subject to true-up and established Rider C3A.

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 kV transmission line from the existing Surry switching station in Surry County to a new Skiffes Creek switching station in James City County, and approximately 20 miles 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. The mandate making the U.S. Court of Appeals for the D.C. Circuit’s March order effective will not be issued until May 2019 at the earliest and may be revised based on the petitions for rehearing. This matter is pending.

Additional Virginia Power electric transmission projects approved or applied for in 2019 are as follows:

Description and Location

of Project

Application

Date

Approval

Date

Type of

Line

Miles of

Lines

Cost Estimate

(millions)

Partial rebuild of overhead transmission lines in Alleghany County, Virginia and Covington, Virginia

August 2018

April 2019

138 kV

Rebuild and operate between Lanexa and the Northern Neck in Virginia

June 2018

February 2019

230 kV

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

Pending

230 kV

125

Rebuild and operate between Valley, Virginia and Mt. Storm, West Virginia

April 2019

Pending

500 kV

290

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. This case is pending.

South Carolina Regulation

DSM Programs

DESC has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In January 2019, DESC filed an application with the South Carolina Commission seeking approval to recover $30 million of costs and net lost revenues associated with these programs, along with an incentive to invest in such programs. In April 2019, the South Carolina Commission approved the request for the rate year beginning ~~September 1, 2018. The Virginia Commission’s order required an adjustment to Rider T1 to begin providing projected benefits associated~~ with the 2017 Tax Reform Act to customers in rates effective September 1, 2018. Such projected benefits were not included in the underlying transmission formula rates approved by FERC. Also in August 2018, Virginia Power filed a petition with the Virginia Commission seeking limited reconsideration and rehearingfirst billing cycle of ~~this approval to adjust the total revenue requirement to $636 million. The reconsideration was granted and this matter is pending.~~

~~Coastal Virginia Offshore Wind Project~~

In August 2018, Virginia Power filed a petition with the Virginia Commission seeking a prudency determination as provided in the Grid Transformation and Security Act of 2018 with respect to the proposed Coastal Virginia Offshore Wind Project consisting of two 6 MW wind turbine generators located approximately 27 miles off the coast of Virginia Beach, Virginia in federal waters, and for a CPCN, if necessary, for the generation tie line connecting the generators to shore. This project is expected to cost approximately $300 million and to be installed by the end of 2020. This matter is pending.

~~Electric Transmission Projects~~

In August 2018, Virginia Power filed an application with the Virginia Commission for a CPCN for a partial rebuild of 138 kV overhead transmission lines in Alleghany County, Virginia and Covington, Virginia. The total estimated cost of the project is approximately $15 million. This matter is pending.

In September 2018, the Virginia Commission granted Virginia Power a CPCN to rebuild and operate in Augusta County, Virginia approximately 18 miles of existing 500 kV transmission line between the Dooms substation and the Valley substation, along with associated substation work. The total estimated cost of the project is approximately $65 million.

In September 2018, the Virginia Commission granted Virginia Power a CPCN to build and operate in Fairfax County, Virginia approximately 4 miles of 230 kV transmission line between the Idylwood and Tysons substations, along with associated substation work. The total estimated cost of the project is approximately $125 million.

~~North Carolina Regulation~~

In August 2018, Virginia Power submitted its annual filing to the North Carolina Utilities Commission to adjust the fuel component of its electric rates. Virginia Power proposed a total $24 million increase to the fuel component of its electric rates for the rate year beginning February 1,May 2019. As a mitigation alternative, Virginia Power proposed recovering 50% in the February 1, 2019 to the January 31, 2020 rate period and the remaining 50% in the following rate period. This case is pending.

Ohio Regulation

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 ~~September 2018,~~April 2019, the Ohio Commission approved East Ohio’s application ~~requesting approval~~to adjust the PIR cost recovery for 2018 costs. The filing reflects a gross plant investment for 2018 of $202 million, cumulative gross plant investment of $1.6 billion and a revenue requirement of $190 million.

AMR Program

In 2007, East Ohio began installing automated meter reading technology for its ~~UEX Rider~~1.2 million customers in Ohio. In April 2019, the Ohio Commission approved East Ohio’s application to ~~reflect~~adjust the AMR cost recovery for 2018 costs. The filing reflects a ~~refund~~revenue requirement of ~~over-recovered accumulated bad~~$4 million.

CEP Program

In 2011, East Ohio began CEP which enables East Ohio to defer depreciation expense, property tax expense and carrying costs at the debt ~~expense~~rate of ~~$11~~6.5% on capital investments not covered by its PIR program to expand, upgrade or replace its pipeline system and information technology systems as well as investments necessary to comply with the Ohio Commission or other government regulation. In May 2019, East Ohio filed an application for an alternative rate plan to establish a CEP rider to recover existing CEP-related deferrals and to establish an ongoing recovery mechanism for future deferrals. The filing reflects cumulative gross plant investment of $723 million ~~as of March 31,~~through 2018 and ~~recovery~~a revenue requirement of ~~prospective net bad debt expense projected to total $16 million for the twelve-month period from April 2018 to March 2019.~~$83 million. This matter is pending.

Utah and Wyoming Regulation

In ~~October 2018,~~April 2019, Questar Gas filed a request with the Utah Commission ~~denied Questar Gas’ request~~ for pre-approval to construct an LNG ~~peaking~~ storage facility with a liquefaction rate of 8.2 million cubic feet per day. This pre-approval process allows Questar Gas ~~is reviewing the order and assessing its options, which include filing supplemental information with~~to receive a prudency determination from the Utah Commission ~~for reconsideration.~~

~~In October 2018, Questar Gas submitted filings with both~~before making a capital investment in the facility. Under the pre-approval statute, the Utah Commission has 180 days to make a prudency determination. This matter is pending.

FERC – Gas

In February 2019, Cove Point submitted its annual electric power cost adjustment to FERC requesting approval to recover $24 million. FERC approved the adjustment in March 2019.

Note 14. Leases

At March 31, 2019, the Companies had the following lease assets and liabilities recorded in the Consolidated Balance Sheets:

	March 31, 2019
(millions)
Dominion Energy
Lease assets:
Operating lease assets	$	486
Finance lease assets⁽¹⁾		79
Total lease assets	$	565
Lease liabilities:
Operating lease liabilities⁽²⁾	$	62
Finance lease liabilities⁽³⁾		14
Total lease liabilities - current		76
Operating lease liabilities		418
Finance lease liabilities⁽⁴⁾		66
Total lease liabilities - noncurrent		484
Total lease liabilities	$	560
Virginia Power
Operating lease assets	$	202
Finance lease assets⁽¹⁾		8
Total lease assets	$	210
Lease liabilities:
Operating lease liabilities⁽²⁾	$	33
Finance lease liabilities⁽³⁾		2
Total lease liabilities - current		35
Operating lease liabilities		169
Finance lease liabilities⁽⁴⁾		5
Total lease liabilities - noncurrent		174
Total lease liabilities	$	209
Dominion Energy Gas
Operating lease assets	$	63
Finance lease assets⁽¹⁾		3
Total lease assets	$	66
Lease liabilities:
Operating lease liabilities⁽²⁾	$	12
Finance lease liabilities⁽³⁾		1
Total lease liabilities - current		13
Operating lease liabilities		49
Finance lease liabilities⁽⁴⁾		3
Total lease liabilities - noncurrent		52
Total lease liabilities	$	65

(1)	Included in property, plant and equipment in the Companies’ Consolidated Balance Sheets, net of $29 million, $2 million and $1 million of accumulated amortization at Dominion Energy, Virginia Power and Dominion Energy Gas, respectively, at March 31, 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 March 31, 2019 includes property, plant and equipment and accumulated depreciation of $2.8 billion and $294 million, respectively, related to facilities subject to power purchase agreements under which Dominion Energy is the lessor.

For the three months ended March 31, 2019, total lease cost associated with the Companies’ lessee leasing arrangements consisted of the following:

	Three Months Ended March 31, 2019
(millions)
Dominion Energy
Finance lease cost:
Amortization	$	3
Interest		1
Operating lease cost		25
Short-term lease cost		6
Variable lease cost		2
Total lease cost	$	37
Virginia Power
Operating lease cost	$	10
Short-term lease cost		2
Variable lease cost		1
Total lease cost	$	13
Dominion Energy Gas
Operating lease cost	$	4
Short-term lease cost		1
Total lease cost	$	5

For the three months ended March 31, 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:

	Three Months Ended March 31, 2019
(millions)
Dominion Energy
Operating cash flows for finance leases	$	1
Operating cash flows for operating leases		32
Financing cash flows for finance leases		3
Virginia Power
Operating cash flows for operating leases		13
Dominion Energy Gas
Operating cash flows for operating leases		5

In addition to the amounts disclosed above, Dominion Energy’s Consolidated Statement of Income for the three months ended March 31, 2019 includes $29 million and $23 million of rental revenue and depreciation expense, included in operating revenue and depreciation, depletion and amortization, respectively, related to facilities subject to power purchase agreements under which Dominion Energy is the lessor.

At March 31, 2019, the weighted average remaining lease term and weighted discount rate for the Companies’ finance and operating leases were as follows:

	March 31, 2019
Dominion Energy
Weighted average remaining lease term - finance leases	7 years
Weighted average remaining lease term - operating leases	21 years
Weighted average discount rate - finance leases		4.66	%
Weighted average discount rate - operating leases		4.61	%
Virginia Power
Weighted average remaining lease term - finance leases	6 years
Weighted average remaining lease term - operating leases	16 years
Weighted average discount rate - finance leases		4.99	%
Weighted average discount rate - operating leases		4.47	%
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		5.04	%
Weighted average discount rate - operating leases		4.44	%

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	$	54		$	14		$	30		$	2		$	11		$	1
2020		66			16			36			1			13			1
2021		58			14			31			1			11			1
2022		49			12			24			1			9			1
2023		39			9			19			1			6			-
After 2023		532			33			162			2			24			1
Total undiscounted lease payments		798			98			302			8			74			5
Present value adjustment		(318	)		(18	)		(100	)		(1	)		(13	)		(1	)
Present value of lease liabilities	$	480		$	80		$	202		$	7		$	61		$	4

Future Leasing Arrangement

In July 2016, Dominion Energy signed an agreement with a lessor 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 $365 million, to fund the estimated project costs. The project is expected to be substantially completed in the second quarter of 2019. 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, which totaled $310 million at March 31, 2019. If the project is terminated under certain events of default, Dominion Energy could be required to pay up to 89.9% of the then funded amount. For specific full recourse events, Dominion Energy could be required to pay up to 100% of the then funded amount.

The five-year lease term will commence once construction is substantially complete and the ~~Wyoming Commission~~facility is able to be occupied. Upon its commencement, the lease for the facility will be classified as a finance lease. At the end of the initial lease term, Dominion Energy can (i) extend the term of the lease for an ~~approximately $48 million gas cost decrease reflecting forecasted decreases in commodity costs. The Utah Commission~~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 ~~Wyoming Commission both approved~~proceeds from the ~~filings in October 2018 with rates effective November 2018.~~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% of project costs, for the difference between the project costs and sale proceeds.

Note ~~14.~~15. Variable Interest Entities

There have been no significant changes regarding the entities the Companies consider VIEs as described in Note 15 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018.

Dominion Energy

At March 31, 2019 and December 31, 2018, Dominion Energy’s securities due within one year includes $29 million and $31 million, respectively, and long-term debt ~~include $27~~includes $301 million and ~~$326~~$299 million, respectively, of debt issued ~~in 2016~~ 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~~has long-term power and capacity contracts with ~~three~~one non-utility ~~generators. Contracts~~generator with ~~two of these non-utility generators expired in the third quarter 2017 leaving a remaining~~an aggregate summer generation capacity of approximately 218 MW. Virginia Power is not subject to any risk of loss from this potential VIE other than its remaining purchase commitments which totaled ~~$163~~$159 million as of ~~September 30, 2018.~~March 31, 2019. Virginia Power paid $13 million and ~~$17~~$13 million for electric capacity and $4$1 million and $5 million for electric energy to the non-utility ~~generators~~generator in the three months ended ~~September 30,~~March 31, 2019 and 2018, and 2017, respectively. Virginia Power paid $38 million and $73 million for electric capacity and $14 million and $20 million for electric energy to non-utility generators in the nine months ended September 30, 2018 and 2017, respectively.

Virginia Power and Dominion Energy Gas

Virginia Power and Dominion Energy Gas purchased shared services from DES, an affiliated VIE, of ~~$79~~$89 million and ~~$31~~$35 million for the three months ended ~~September 30, 2018, $83~~March 31, 2019 and $89 million and ~~$31~~$32 million for the three months ended ~~September 30, 2017, $251 million and $94 million for the nine months ended September 30,~~March 31, 2018, ~~and $251 million and $93 million for the nine months ended September 30, 2017,~~ respectively. Virginia Power and Dominion Energy Gas’ Consolidated Balance Sheets included amounts due to DES of ~~$23~~$22 million and $11 million, respectively, at ~~September 30, 2018,~~March 31, 2019, and ~~$36~~$107 million and ~~$14~~$46 million, respectively, at December 31, ~~2017,~~2018, recorded in payables to ~~affiliates in the Consolidated Balance Sheets.~~affiliates.

Note ~~15.~~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

InAt March ~~2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. At September 30, 2018,~~31, 2019, 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

2,928

132

2,940

6,000

2,393

3,517

(1)	This credit facility matures in March 2023 and can be used by the ~~Companies~~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.

~~Questar Gas’ short-term financing is supported through its access~~In addition to the credit facility mentioned above, Dominion Energy also has a credit facility with a maturity date in June 2020 which allows Dominion Energy to issue up to approximately $21 million in letters of credit. At March 31, 2019, Dominion Energy had $21 million in letters of credit outstanding under this agreement.

In March 2019, DESC’s existing $700 million credit facility was terminated and DESC was added as ~~co-borrower~~a borrower to the joint revolving credit facility discussed above with Dominion Energy, Virginia Power, ~~and~~ Dominion Energy Gas and Questar Gas. At ~~September 30, 2018,~~March 31, 2019, the sub-limit for ~~Questar Gas~~DESC was ~~$250~~$500 million.

South Carolina Fuel Company, Inc.’s existing credit facility was terminated in February 2019. SCANA and PSNC’s existing credit facilities were terminated in March 2019. Liquidity needs for these entities may be satisfied through short-term intercompany borrowings from Dominion Energy.

In addition to the credit ~~facility~~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 30, 2018,~~March 31, 2019, no amounts were outstanding under either of these facilities.

In October 2018, Dominion Energy entered into a credit agreement, which allows Dominion Energy to issue up to approximately $21 million in letters of credit. Additionally, in October 2018, Dominion Energy issued $16 million in letters of credit under this agreement. The facility terminates in June 2020.

In February and June 2018, Dominion Energy borrowed $950 million and $500 million, respectively, under 364-Day Term Loan Agreements that bore interest at a variable rate. In September 2018, the principal outstanding plus accrued interest for both borrowings was repaid.

~~In March 2018,~~2019, Dominion Energy Midstream ~~entered into a~~terminated its $500 million revolving credit ~~facility. The credit~~ facility ~~matures in March 2021, bears interest at a variable rate, and can be used~~subsequent to ~~support bank borrowings and~~repaying the ~~issuance~~outstanding balance of ~~commercial paper, as well as to support up to $250 million of letters of credit. At September 30, 2018, Dominion Energy Midstream had~~ $73 million, ~~outstanding under this credit facility.~~plus accrued interest.

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 ~~Companies~~borrowers under the credit facility and for other general corporate purposes.

At ~~September 30, 2018,~~March 31, 2019, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Dominion Energy Gas, ~~and~~ 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

934

6,000

595

(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 ~~Questar Gas.~~DESC. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the ~~Companies~~borrowers under the credit facility multiple times per year. At ~~September 30, 2018,~~March 31, 2019, 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.

In addition to the credit facility commitments mentioned above, Virginia Power also had a $100 million credit facility with a maturity date of April 2020. In March 2018, Virginia Power redeemed its variable rate tax-exempt financings supported by this credit facility and terminated the facility.

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 ~~Companies~~borrowers under the credit facility and for other general corporate purposes.

At ~~September 30, 2018,~~March 31, 2019, Dominion Energy Gas' share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, Virginia Power, ~~and~~ 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

141

—

1,500

280

—

(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 ~~Questar Gas.~~DESC. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the ~~Companies~~borrowers under the credit facility multiple times per year. At ~~September 30, 2018,~~March 31, 2019, 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 ~~January 2018,~~February 2019, Dominion Energy ~~Questar Pipeline~~Midstream repaid its $300 million variable rate term loan agreement due in December 2019 at the principal outstanding plus accrued interest.

In February and March 2019, DESC purchased certain of its first mortgage bonds having an aggregate purchase price of $1.2 billion pursuant to tender offers. Also in March 2019, SCANA purchased certain of its medium term notes having an aggregate purchase price of $300 million pursuant to a tender offer. Both DESC tender offers and the SCANA tender offer expired in the first quarter of 2019.

In March 2019, Dominion Energy issued ~~through private placement, $100~~$400 million of ~~3.53% senior notes and $150 million of 3.91%~~4.60% senior notes that mature in ~~2028 and 2038, respectively. The proceeds were used to repay maturing long-term debt.~~2049.

In March ~~2018, Virginia Power issued $700 million of 3.80% senior notes that mature in 2028.~~

~~In March 2018, Virginia Power redeemed $100 million of its variable rate tax-exempt financings which would otherwise have matured in 2024, 2026 and 2027.~~

~~In April 2018, Questar Gas issued through private placement $50 million of 3.30% senior notes and $100 million of 3.97% senior notes that mature in 2030 and 2047, respectively.~~

~~In May 2018,~~2019, Dominion Energy issued ~~through private placement $500~~an additional $200 million of ~~variable rate senior notes that mature in 2020.~~

~~In June 2018, Dominion Energy issued $300 million of~~its 4.25% senior notes that mature in 2028.

In ~~June 2018, Dominion Energy Gas issued $500~~April 2019, Virginia Power provided notice to redeem its $40 million ~~of variable rate senior notes that mature in 2021.~~

In September 2018, Cove Point closed on an up to $3.0 billion term loan that is secured by Dominion Energy’s common equity interest in Cove Point, bears interest at a variable rate and matures in 2021. In accordance with the terms5.0% Economic Development Authority of the ~~term loan, Cove Point borrowed $2.0 billion at closing and can borrow up to an additional $1.0 billion by~~County of Chesterfield Pollution Control Refunding Revenue Bonds, Series 2009A, due in 2023. At March 31, 2019, the end of 2018. Under the terms of the term loan, Cove Point is restricted from issuing certain debt, selling the Cove Point LNG Facility, paying distributions to Dominion Energy or taking certain other actions without necessary approvals.

~~In November 2018, Eagle Solar issued through private placement $362 million of 4.82% senior secured notes which mature~~bonds were included in December 2042. The debt is nonrecourse to Dominion Energy and is secured by Eagle Solar’s interest in certain merchant solar facilities. The proceeds were used for the reimbursement of equity amounts previously invested by Dominion Energysecurities due within one year in the ~~acquisition, development, or construction of~~Consolidated Balance Sheets. The bonds were redeemed in May 2019 at the ~~projects in Eagle Solar.~~principal outstanding plus accrued interest.

Noncontrolling Interest in Dominion Energy Midstream

In ~~May 2018, all~~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 ~~subordinated units~~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 ~~Midstream held by Dominion Energy were converted into~~ common ~~units on a 1:1 ratio following~~stock. Immediately prior to the ~~payment of Dominion Energy Midstream’s distribution for the first quarter of 2018. In June 2018, Dominion Energy, as general~~closing, each Series A Preferred Unit representing limited partner ~~exercised an incentive distribution right reset as defined~~interests in Dominion Energy ~~Midstream’s partnership agreement and received 27 million~~Midstream was converted into common units representing limited partner interests in Dominion Energy ~~Midstream. As~~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 ~~result of~~change in a parent company’s ownership interest in a consolidated subsidiary. Because Dominion Energy controls Dominion Energy Midstream both before and after the ~~increase~~merger, the changes in ~~its~~Dominion Energy’s ownership interest in Dominion Energy Midstream were accounted for as an equity transaction and no gain or loss was recognized. In connection with the merger, Dominion Energy ~~recorded a decrease~~recognized $40 million of income taxes in ~~noncontrolling interest,~~equity primarily attributable to establishing additional regulatory liabilities related to excess deferred income taxes and ~~a corresponding increase~~changes 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.~~state income taxes.

Issuance of Common Stock

~~At-the-Market Programs~~

~~In June 2017,~~See Note 3 to the Consolidated Financial Statements for information on the issuance of Dominion Energy ~~filed an SEC shelf registration statement for the sale of debt and equity securities including the ability to sell~~ 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.

At-the-Market Program

Dominion Energy has an at-the-market ~~program. Also, in June 2017, Dominion Energy entered into three separate sales agency agreements to effect sales under the~~ program ~~and~~ pursuant to which it ~~was able~~may offer common stock as discussed in Note 19 to ~~offer up to $500 million aggregate amount~~the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018. In the first quarter of

~~its common stock. In January 2018,~~ 2019, Dominion Energy ~~provided sales instructions to one of the sales agents and~~ issued ~~6.6~~2.1 million shares ~~through at-the-market issuances~~ and received cash proceeds of ~~$495~~$154 million, net of fees and commissions paid of $5$2 million. Following these issuances, Dominion Energy ~~had no remaining~~has the ability to issue ~~stock~~$645 million of securities under ~~the 2017 sales agency agreements and completed the~~its existing at-the-market program. In February 2018, Dominion Energy entered into six separate sales agency agreements to effect sales under a new at-the-market program pursuant to which it may offer from time to time up to $1.0 billion aggregate amount of its common stock. These agreements replaced the sales agency agreements entered into by Dominion Energy in June 2017. Sales of common stock can be made by means of privately negotiated transactions, as transactions on the New York Stock Exchange at market prices or in such other transactions as are agreed upon by Dominion Energy and the sales agents in conformance with applicable securities laws. No issuances have occurred under these agreements in 2018.

~~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 three million shares of Dominion Energy common stock, which the underwriters exercised with respect to approximately 2.1 million shares in April 2018. Dominion Energy entered into separate forward sale agreements with the forward purchasers with respect to the additional shares. Except in certain specified circumstances that would require physical share settlement, Dominion Energy may elect physical, cash or net share settlement of the forward sale agreements on or before December 31, 2018. At the initial forward sale price of approximately $67.33 per share, Dominion Energy expects the net proceeds from full physical settlement of the forward sales agreements to be approximately $1.5 billion (after deducting underwriting discounts, but before deducting expenses, and subject to forward price adjustments under the forward sale agreements). Pursuant to a cash settlement of the forward sale agreements, Dominion Energy would expect to receive an amount of net proceeds that is significantly lower than estimated above in connection with the full physical settlement, and Dominion Energy may not receive any net proceeds (or may owe cash, which could be a significant amount, to the forward purchasers). If the forward sale agreements are net share settled in full, Dominion Energy would not receive any cash proceeds from the forward purchasers (and may be required to deliver shares of our common stock to the forward purchasers). The forward sale transactions will be classified as equity transactions, because they are indexed to Dominion Energy’s common stock and physical settlement is within Dominion Energy’s control.

Note ~~16.~~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 ~~for which~~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 ~~for which~~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

The MATS rule requires coal- and oil-fired electric utility steam generating units to meet strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. ~~Following a one-year compliance extension granted by the VDEQ and an additional one-year extension under an EPA Administrative Order,~~ Virginia Power ceased operating the coal units at Yorktown power station in April 2017 to comply with the rule.

In June 2017, the DOE issued an order to PJM to direct Virginia Power to operate Yorktown power station’s Units 1 and 2 as needed to avoid reliability issues on the Virginia Peninsula. The order was effective for 90 days and can be reissued upon PJM’s request, if necessary, until required electricity transmission upgrades are ~~completed approximately 23 months following the receipt in July 2017 of final permits and approvals for construction.~~completed. Beginning in August 2017, PJM filed requests for 90-day renewals of the DOE order. The most recent order ~~which the DOE has granted. The current renewal is effective until December 2018. The Sierra Club has challenged the DOE order~~expired in March 2019 and ~~certain renewal requests, all of which have been denied by the DOE.~~Units 1 and 2 were retired.

In ~~August~~December 2018, the EPA ~~announced~~issued a proposed rule to reverse its previous finding that ~~it will move ahead with a draft proposal to reconsider the MATS rule and determine whether~~ it is appropriate and necessary to regulate toxic emissions from power plants. ~~At this time, it is uncertain whether~~However, the emissions standards and other requirements of the MATS rule would remain in place as the EPA ~~will repeal~~is not proposing to remove coal and oil fired power plants from the ~~rule in its entirety, establish new, less stringent emission standards or retain the standards at current levels.~~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 Virginia Power is complying with the applicable requirements of the rule and does not expect any adverse impacts to its operations at this time.

Ozone Standards

In October 2015, the EPA issued a final rule tightening the ozone standard from 75-ppb to 70-ppb. To comply with this standard, in April 2016 Virginia Power submitted the NO_X Reasonable Available Control Technology analysis for Unit 5 at Possum Point power station. In December 2016, the VDEQ determined that NO_X reductions are required on Unit 5. In October 2017, Virginia Power proposed to install NO_X controls by mid-2019 with an expected cost in the range of $25 million to $35 million. In April 2018, Virginia Power submitted an application with the VDEQ containing an alternative plan for compliance in lieu of installing NO_X controls on Unit 5 at Possum Point. The alternative plan includes operating restrictions during the ozone season through 2021 while allowing for continued operation to meet PJM capacity commitments and calls for the permanent retirement of the unit by 2021. ~~This application is pending.~~In January 2019, the VDEQ issued a state operating permit that requires either the installation and operation of selective non-catalytic NO_X reduction technology by June 2019 or for Virginia Power to enter into an agreement with the VDEQ by June 2019 committing to retiring the unit by June 2021 with ozone season operating restrictions in the interim. In March 2019, Virginia Power entered into an agreement with the VDEQ to retire Unit 5 by 2021. In addition, Virginia Power ~~plans to place~~placed two natural gas-fired units at the facility into cold reserve in December 2018. ~~Due to the uncertainty surrounding a final plan for compliance with this ozone standard, Dominion Energy and~~In March 2019, Virginia Power ~~are currently unable to predict the outcome of this matter which could be material to Dominion Energy and Virginia Power’s results of operations, financial condition and/or cash flows.~~permanently retired these units. See Note 2 for more information.

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.

NO_X ~~and VOC Emissions~~

~~In April 2016, the Pennsylvania Department of Environmental Protection issued final regulations, with an effective date of January 2017, to reduce NO~~_X and VOC emissions from combustion sources. To comply with the regulations, Dominion Energy Gas is installing emission control systems on existing engines at several compressor stations in Pennsylvania. The compliance costs associated with engineering and installation of controls and compliance demonstration with the regulation are expected to be approximately $35 million.

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 a new 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 ~~April 2017,~~October 2018, the EPA issued a notice that it is reviewing the rule and, if appropriate, will issue a rulemaking to suspend, revise or rescind the June 2016 final NSPS for certain oil and gas facilities. In June 2017, the EPA published notice of reconsideration and partial stay of the rule for 90 days and proposed extending the stay for two years. In July 2017, the U.S. Court of Appeals for the D.C. Circuit vacated the 90-day stay. In November 2017, the EPA solicited comments on the proposed two-year stay of the June 2016 NSPS rules and in October 2018, 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. Until the proposed rule 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.

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 ~~statements.~~condition and/or cash flows.

In addition, the EPA continues to evaluate its policy regarding the consideration of CO₂ emissions from biomass projects when determining whether a stationary source meets the PSD and Title V applicability thresholds, including those for 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's~~Energy and Virginia ~~Power's financial statements.~~

~~Methane Emissions~~

In July 2015, the EPA announced the next generation of its voluntary Natural Gas STAR Program, the Natural Gas STAR Methane Challenge Program. The program covers the entire natural gas sector from production to distribution, with more emphasis on transparency and increased reporting for both annual emissions and reductions achieved through implementation measures. In March 2016, East Ohio, Hope, DETI and Questar Gas joined the EPA as founding partners in the new Methane Challenge Program and submitted implementation plans in September 2016. DECG joined the EPA’s voluntary Natural Gas STAR Program in July 2016 and submitted an implementation plan in September 2016. Dominion Energy and Dominion Energy Gas do not expect the costs related to these programs to have a material impact on theirPower’s results of operations, financial condition and/or cash flows.

Water

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

In October 2014, the final regulations under Section 316(b) of the CWA that govern existing facilities and new units at existing facilities that employ a cooling water intake structure and that have flow levels exceeding a minimum threshold became effective. The rule establishes a national standard for impingement based on seven compliance options, but forgoes the creation of a single technology standard for entrainment. Instead, the EPA has delegated entrainment technology decisions to state regulators. State regulators are to make case-by-case entrainment technology determinations after an examination of five mandatory facility-specific factors, including a social cost-benefit test, and six optional facility-specific factors. The rule governs all electric generating stations with water withdrawals above two MGD, with a heightened entrainment analysis for those facilities over 125 MGD. Dominion Energy and Virginia Power currently have 1314 and 11eight facilities, respectively, that may be subject to the final regulations. Nine units at Virginia Power’s facilities that are subject to regulations under Section 316(b) of the CWA have been or will be placed into cold reserve. While in cold reserve, applicable requirements under Section 316(b) of the CWA continue to apply to these units. Dominion Energy anticipates that it will have to install impingement control technologies at ~~many~~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. While the impacts of this rule could be material to Dominion ~~Energy’s~~Energy and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory ~~framework~~frameworks in South Carolina and Virginia ~~provides~~provide rate recovery mechanisms that could substantially mitigate any such impacts for ~~Virginia Power.~~the regulated electric utilities.

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. ~~Virginia Power has eight facilities subject to the final rule.~~ In April 2017, the EPA granted two separate petitions for reconsideration of the Effluent Limitations Guidelines final rule and stayed future compliance dates in the rule. Also in April 2017, the U.S. Court of Appeals for the Fifth Circuit granted the U.S.’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’s~~Energy and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory ~~framework~~frameworks in South Carolina and Virginia ~~provides~~provide rate recovery mechanisms that could substantially mitigate any such impacts for ~~Virginia Power.~~the regulated electric utilities.

Waste Management and Remediation

The CERCLA, as amended, provides for immediate response and removal actions coordinated by the EPA in the event of threatened releases of hazardous substances into the environment and authorizes the U.S. government either to clean up sites at which hazardous substances have created actual 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 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.

From time to time, Dominion Energy, Virginia Power or Dominion Energy Gas may be identified as a potentially responsible party to a Superfund site. The EPA (or a state) can either allow such a party to conduct and pay for a remedial investigation, feasibility study and remedial action or conduct 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 may be responsible for the costs of remedial investigation and actions under the Superfund law or other laws or regulations regarding 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 1922 former manufactured gas plant sites, three of which pertain to Virginia Power and 12 of which pertain to Dominion Energy Gas. Studies conducted by other utilities at their former manufactured gas plant sites have indicated that those sites contain coal tar and other potentially harmful materials. None of the former sites with which the Companies are associated is under investigation by any state or federal environmental agency. At ~~two~~one 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 voluntary 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 mid-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 four 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 one 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. Due to the uncertainty surrounding the other sites, the Companies 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.

~~Appalachian Gateway~~SCANA Legal Proceedings

~~Pipeline Contractor Litigation~~

~~Following the completion~~The following describes certain legal proceedings to which SCANA or DESC were a party to at closing of the ~~Appalachian Gateway project~~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.

Ratepayer Class Actions

In May 2018, a consolidated complaint against DESC, SCANA and the State of South Carolina was filed in ~~2012, DETI received multiple change order requests~~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 ~~claims for additional payments from~~sources be placed in a ~~pipeline contractor~~constructive trust for the ~~project.~~ benefit of ratepayers and sought specific performance of the alleged implied contract to construct the NND Project.

In ~~July 2015,~~December 2018, the ~~contractor~~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 has scheduled a fairness hearing on the settlement in May 2019. Any distribution from the escrow account is subject to court approval. As a result, in the first quarter of 2019, Dominion Energy recorded a charge of $169 million ($126 million after-tax) charge, reflected in impairment of assets and other charges in the Consolidated Statements of Income.

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. In December 2018, Santee Cooper filed its answer to the plaintiffs' fourth amended complaint and filed cross claims against ~~DETI~~DESC. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

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 ~~Western~~ District of ~~Pennsylvania.~~ South Carolina. 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. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

Shareholder Derivative Actions

In ~~March 2016,~~September 2017, a purported shareholder derivative action was filed against certain former executive officers and directors of SCANA in the ~~Pennsylvania court granted DETI’s~~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 defendants have filed a motion to ~~transfer~~dismiss the consolidated action in favor of the pending federal derivative action. In February 2019, one action was voluntarily dismissed. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

In November 2017, a purported 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, the court denied the defendants’ motions to dismiss and in October 2018, the court denied SCANA’s motion to stay all proceedings pending investigation by a Special Litigation Committee, with leave to refile after the SCANA Merger Approval Order was issued. The plaintiffs have agreed to a stay of this action on the condition that defendants file a motion for judgment on the pleadings, which was filed in January 2019. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

Merger Actions

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 ~~Eastern~~ District of ~~Virginia. In July 2016, DETI~~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 has been consolidated with a similar appeal in the Metzler lawsuit discussed below and remains pending. In October 2018, the U.S. District Court for the District of South Carolina granted Dominion Energy’s motion to stay pending appeal. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

In February 2018, a purported class action was filed against certain former directors of SCANA and DESC and Dominion Energy 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 has been consolidated with the City of Warren Lawsuit. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

Federal Court 10b-5

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. 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 ~~2017,~~2019, the ~~court dismissed three~~U.S. District Court for the District of ~~eight counts~~South Carolina granted in part and denied in part the defendants’ motions to dismiss. This case is pending. Dominion Energy cannot currently estimate the financial statement impacts of this matter, but there could be a material impact to its results of operations, financial condition and/or cash flows.

Employment Class Action and Indemnification

In July 2018, a case filed in the ~~complaint. In May 2017,~~U.S. District Court for the ~~contractor withdrew one~~District of South Carolina was certified as a class action on behalf of persons who were formerly employed at the NND Project. The plaintiffs allege, among other things, that SCANA, 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 are estimated to be as much as $75 million. DESC as co-owner of the ~~counts~~NND Project would have a 55% proportional share in any damages owed upon the ultimate outcome. The ultimate loss could rise due to the Fluor defendants seeking indemnification from DESC.

In September 2018, a case was filed in the ~~complaint.~~ 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, ~~DETI~~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. Dominion Energy is currently unable to make an estimate of the potential impacts to its consolidated financial statements related to this matter. 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, and recorded a $20 million liability in its Consolidated Balance Sheet as of March 31, 2019.

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 ~~contractor entered~~Staff of the SEC’s Division of Enforcement seeking documents related to the NND Project. 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 cooperating fully with the investigations, including responding to additional subpoenas and document requests; however, Dominion Energy cannot currently predict whether or to what extent SCANA or DESC may incur a ~~partial settlement~~material liability.

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 ~~a release~~the 2017 and 2018 delivery years. DESC denies that it is in breach of ~~certain claims. In August 2018, DETI paid $14 million in accordance with~~the agreement and believes that it has reduced its purchase quantity within the terms of ~~a settlement agreement reached between~~ the ~~parties, resolving~~agreement. Dominion Energy cannot determine the outcome or timing of this matter.

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

Westinghouse has indicated that some unsecured creditors have sought or may seek amounts beyond what Westinghouse allocated when it submitted its reorganization plan to the Bankruptcy Court. 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 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. DESC does not believe that the claims asserted related 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. To the extent any such claim is determined to be valid, DESC may be responsible for paying its 55% share thereof.

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. To the extent any such claim is determined to be valid, DESC may be responsible for paying its 55% share thereof.

Appalachian Gateway

Gas Producers Litigation

In connection with the Appalachian Gateway project, Dominion Energy Field Services, Inc. entered into contracts for firm purchase rights with a group of small gas producers. In June 2016, the gas producers filed a complaint in the Circuit Court of Marshall County, West Virginia against Dominion Energy, DETI and Dominion Energy Field Services, Inc., among other defendants, claiming that the contracts are unenforceable and seeking compensatory and punitive damages. During the third quarter of 2016, Dominion Energy, DETI and Dominion Energy Field Services, Inc. were served with the complaint. Also in the third quarter of 2016, Dominion Energy and DETI, with the consent of the other defendants, removed the case to the U.S. District Court for the Northern District of West Virginia. In October 2016, the defendants filed a motion to dismiss and the plaintiffs filed a motion to remand. In February 2017, the U.S. District Court entered an order remanding the matter to the Circuit Court of Marshall County, West Virginia. In March 2017, Dominion Energy was voluntarily dismissed from the case; however, DETI and Dominion Energy Field Services, Inc. ~~remain~~remained parties to the matter. In April 2017, the case was transferred to the Business Court Division of West Virginia. In January 2018, the court granted the motion to dismiss filed by the defendants on two counts. ~~All other~~In 2019, all claims ~~are pending in~~were settled between Dominion Energy Field Services, Inc. and the ~~Business Court Division of West Virginia. Dominion Energy~~gas producers, and all claims against DETI and Dominion Energy ~~Gas cannot currently estimate financial statement impacts, but there could be a~~Field Services, Inc. were dismissed with no material impact to ~~their~~Dominion Energy or Dominion Energy Gas’ results of operations, financial condition ~~and/~~or cash flows.

Ash Pond and Landfill Closure Costs

In March 2015, the Sierra Club filed a lawsuit alleging CWA violations at Chesapeake power station. In March 2017, the U.S. District Court for the Eastern District of Virginia ruled that impacted groundwater associated with the on-site coal ash storage units was migrating to adjacent surface water, which constituted an unpermitted point source discharge in violation of the CWA. The court, however, rejected Sierra Club’s claims that Virginia Power had violated specific conditions of its water discharge permit. Finding no harm to the environment, the court further declined to impose civil penalties or require excavation of the ash from the site as Sierra Club had sought. In July 2017, the court issued a final order requiring Virginia Power to perform additional specific sediment, water and aquatic life monitoring at and around the Chesapeake power station for a period of at least two years. The court further directed Virginia Power to apply for a solid waste permit from the VDEQ that includes corrective measures to address on-site groundwater impacts. In July 2017, Virginia Power appealed the court’s July 2017 final order to the U.S. Court of Appeals for the Fourth Circuit. In August 2017, the Sierra Club filed a cross appeal. In September 2018, the U.S. Court of Appeals for the Fourth Circuit ruled that impacted groundwater associated with coal ash storage at the Chesapeake power station did not constitute point source pollution in violation of the CWA or the station’s water discharge permit. The Sierra Club subsequently filed a petition for rehearing with the U.S. Court of Appeals for the Fourth Circuit, which was denied.

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. ~~Virginia Power~~Dominion Energy currently operates inactive ash ponds, existing ash ponds and CCR landfills subject to the final rule at 11 different facilities, eight ~~different facilities.~~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~~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 two 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. ~~Any changes to the CCR rule would not be effective in Virginia unless and until the VDEQ adopts those changes.~~ 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 ~~does~~do not expect the scope of the U.S. Court of Appeals for the D.C. Circuit’s decision to impact ~~its~~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 ~~requires~~required Virginia Power to conduct an assessment of closure alternatives for the ash ponds at these four 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 ~~requires~~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 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, ~~in the second quarter of 2018~~ 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. In addition, Virginia Power revised its estimated cash flows for the existing ARO ~~and a related environmental liability~~ related to future ash pond and landfill closure costs, ~~of $131 million,~~ which resulted in ~~an $81~~a decrease of $202 million and a corresponding $113 million ($6084 million after-tax) ~~charge recorded~~benefit in other operations and maintenance expense in ~~its~~the 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.~~Income. The actual AROs related to ~~the CCR rule~~CCRs may vary substantially from the estimates used to record the obligation.

~~Cove Point~~

In September 2014, FERC issued an order granting authorization for Cove Point to construct, modify and operate the Liquefaction Project at the Cove Point facility, which enables the facility to liquefy domestically-produced natural gas and export it as LNG. In March 2018, Cove Point received authorization from FERC to commence service of the Liquefaction Project, which commenced commercial operations in April 2018.

Two parties have separately filed petitions for review of the FERC order in the U.S. Court of Appeals for the D.C. Circuit, which petitions were consolidated. Separately, one party requested a stay of the FERC order until the judicial proceedings are complete, which the court denied in June 2015. In July 2016, the court denied one party’s petition for review of the FERC order authorizing the Liquefaction Project. The court also issued a decision remanding the other party’s petition for review of the FERC order to FERC for further explanation of FERC’s decision that a previous transaction with an existing import shipper was not unduly discriminatory. In September 2017, FERC issued its order on remand from the U.S. Court of Appeals for the D.C. Circuit, and reaffirmed its ruling in its prior orders that Cove Point did not violate the prohibition against undue discrimination by agreeing to a capacity reduction and early contract termination with the existing import shipper. In October 2017, the party filed a request for rehearing of the FERC order on remand. In August 2018, FERC issued its rehearing order affirming and clarifying its previous orders.

FERC

FERC staff in the Office of Enforcement, Division of Investigations, ~~is conducting~~conducted a non-public investigation of Virginia Power's offers of combustion turbines generators into the PJM day-ahead markets from April 2010 through September 2014. FERC staff notified Virginia Power of its preliminary findings relating to Virginia Power's alleged violation of FERC's rules in connection with these activities. Virginia Power ~~has~~ provided its response to FERC staff's preliminary findings letter explaining why Virginia Power's conduct was lawful and refuting any allegation of wrongdoing. This matter is pending. Virginia ~~Power is cooperating fully with the investigation; however, it cannot currently predict whether or to what extent it may incur~~Power’s Consolidated Balance Sheet as of March 31, 2019 includes a ~~material~~$14 million liability.

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 supporting data and participating 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 Tier 1 recommendations consisting of actions which the staff determined should be started without unnecessary delay. In December 2011, the NRC Commissioners approved the agency staff's prioritization and recommendations, and that same month an appropriations act directed the NRC to require reevaluation of external hazards (not limited to seismic and flooding hazards) as soon as possible.

Based on the prioritized recommendations, in March 2012, the NRC issued orders and information requests requiring specific reviews and actions to all operating reactors, 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 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 each reactor to reevaluate the seismic and external flooding hazards at their site using present-day methods and information, conduct walkdowns of their facilities to ensure protection against the 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 ~~and~~hazards was completed or in review with the NRC in 2018. Reevaluation of the external flooding hazards is expected to continue through ~~2018.~~2019. Dominion Energy and Virginia Power do not currently expect that compliance with the NRC's information requests will materially impact their financial position, results of operations or cash flows during the implementation period. The NRC staff is evaluating the implementation of the ~~longer-term~~longer term Tier 2 and Tier 3 recommendations. 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 2018, the total liability protection per nuclear incident available to all participants in the Secondary Financial Protection Program decreased from $13.4 billion to $13.1 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 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2018, 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. The DOE failed to begin accepting the spent fuel on January 31, 1998, the date provided by the Nuclear Waste Policy Act and by Dominion Energy’s and Virginia Power’s contracts with the DOE. Dominion Energy and Virginia Power have previously received damages award payments and settlement payments related to these contracts.

By mutual agreement of the parties, the settlement agreements are extendable to provide for resolution of damages incurred after 2013. The settlement agreements for the Surry, North Anna and Millstone nuclear power stations have been extended to provide for periodic payments for damages incurred through December 31, 2016, and have been extended to provide for periodic payment of damages through December 31, 2019. 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. 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~~

~~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 ~~also entered in October 2017,~~ 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 in Atlantic Coast Pipeline. As of ~~September 30, 2018,~~March 31, 2019, Atlantic Coast Pipeline ~~had~~has borrowed ~~$1.0~~$1.6 billion against the revolving credit facility and borrowed an additional ~~$132~~$47 million in ~~October 2018.~~the second quarter of 2019. Dominion Energy’s Consolidated Balance Sheets include a liability of ~~$23~~$19 million and $21 million associated with this guarantee agreement at ~~September 30, 2018.~~ March 31, 2019 and December 31, 2018, respectively.

In addition, at ~~September 30, 2018,~~March 31, 2019, Dominion Energy had issued an additional $48 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 30, 2018,~~March 31, 2019, Dominion Energy had issued the following subsidiary guarantees:

	Maximum Exposure		Maximum Exposure
(millions)
Commodity transactions⁽¹⁾	$	2,196	$	2,334
Nuclear obligations⁽²⁾		200		180
Cove Point⁽³⁾		1,900		1,900
Solar⁽⁴⁾		640		659
Other⁽⁵⁾		543		426
Total⁽⁶⁾	$	5,479	$	5,499

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

(2)	Guarantees 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. Also included are guarantees related to certain DGI subsidiaries’ obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of September 30, 2018, Dominion Energy's maximum remaining cumulative exposure under these equity funding agreements is $4 million through 2019 and its maximum annual future contribution is approximately $4 million.

(6)	Excludes Dominion Energy's guarantee for the construction of athe new corporate office property as discussed in Note 22 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017.~~2018.

Additionally, at ~~September 30, 2018,~~March 31, 2019, Dominion Energy had purchased ~~$169~~$175 million of surety bonds, including ~~$70~~$72 million at Virginia Power and ~~$26~~$25 million at Dominion Energy Gas, and authorized the issuance of letters of credit by financial institutions of ~~$132~~$90 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 ~~17.~~18. Credit Risk

The Companies’ accounting policies for credit risk are discussed in Note 23 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017 as updated in Current Report on Form 8-K, filed June 6,~~ 2018.

At ~~September 30, 2018,~~March 31, 2019, Dominion Energy’s gross credit exposure related to energy marketing and price risk management activities totaled ~~$61~~$184 million. Of this amount, investment grade counterparties, including those internally rated, represented ~~41%~~63%. No single counterparty, whether investment grade or non-investment grade, exceeded $9$36 million of exposure. At ~~September 30, 2018,~~March 31, 2019, Virginia Power’s exposure related to wholesale customers totaled ~~$51~~$74 million. Of this amount, investment grade counterparties, including those internally rated, represented ~~48%~~23%. No single counterparty, whether investment grade or non-investment grade, exceeded $9$29 million of exposure. At ~~September 30, 2018,~~March 31, 2019, Dominion Energy Gas’ exposure primarily related to wholesale customers totaled ~~less than $1~~$2 million. Of this amount, investment grade counterparties, including those internally rated, represented 2%65%. No single counterparty, whether investment grade or non-investment grade, exceeded $1 million of exposure.

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 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Dominion Energy would have been required to post ~~$24~~less than $1 million and ~~$62~~$1 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 collateral at ~~September 30, 2018~~March 31, 2019 or December 31, ~~2017~~2018 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The aggregate fair value of all derivative instruments with credit-related contingent provisions that are in a liability position and not fully collateralized with cash was immaterial at ~~September 30, 2018~~both March 31, 2019 and December 31, ~~2017 was $22 million and $65 million, respectively,~~2018, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power and Dominion Energy Gas were ~~not material~~immaterial as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017.~~2018. See Note 9 for further information about derivative instruments.

Note ~~18.~~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 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 30,~~March 31, 2019, Virginia Power’s derivative assets and liabilities with affiliates were both $6 million. At December 31, 2018, Virginia Power’s derivative assets and liabilities with affiliates were ~~$16~~$26 million and ~~$3 million, respectively. At December 31, 2017, Virginia Power’s derivative assets and liabilities with affiliates were $11 million and $5~~$10 million, respectively. See Note 9 for more information.

Virginia Power participates in certain Dominion Energy benefit plans described in Note 21 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, 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 ~~$600~~$661 million and ~~$505~~$632 million, respectively. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, 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 ~~$241~~$265 million and ~~$199~~$254 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 March 31,
	2018		2017		2018		2017		2019		2018
(millions)
Commodity purchases from affiliates	$	196	$	170	$	733	$	519	$	272	$	398
Services provided by affiliates⁽¹⁾		106		109		338		333		119		120
Services provided to affiliates		6		5		17		17		6		6

(1)	Includes capitalized expenditures of ~~$34~~$33 million and ~~$33~~$37 million for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and $109 million and $104 million for the nine months ended September 30, 2018 and 2017,~~ respectively.

Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were ~~$15~~$24 million and ~~$33~~$224 million in short-term demand note borrowings from Dominion Energy as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively. Virginia Power had no outstanding borrowings, net of repayments, under the Dominion Energy money pool for its nonregulated subsidiaries as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017.~~2018. Interest charges related to Virginia Power’s borrowings from Dominion Energy were ~~less than $1 million~~immaterial for the three ~~and nine~~ months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~2018.

There were no issuances of Virginia Power’s common stock to Dominion Energy for the three ~~and nine~~ months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~2018.

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 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, all of Dominion Energy Gas' commodity derivatives were with affiliates. See Notes 7 and 9 for more information. See Note 10 for information regarding transactions with Atlantic Coast Pipeline.

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, ~~2017, as updated in Current Report on Form 8-K, filed on June 6,~~ 2018. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, amounts due from Dominion Energy associated with the Dominion Energy Pension Plan included in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were ~~$763~~$782 million and ~~$734~~$772 million, respectively. At ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Dominion Energy Gas’ amounts due from Dominion Energy associated with the Dominion Energy Retiree Health and Welfare Plan included in noncurrent pension and other postretirement benefit assets in the Consolidated Balance Sheets were ~~$12~~$15 million and $7$14 million, respectively.

DES and other affiliates provide accounting, legal, finance 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 to Dominion Energy Gas on the basis of direct and allocated methods in accordance with Dominion Energy Gas’ 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 Dominion Energy Gas’ significant transactions with DES and other affiliates and related parties:

	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2018		2017		2018		2017		2019		2018
(millions)
Sales of natural gas and transportation and storage services to affiliates	$	17	$	15	$	51	$	51	$	15	$	18
Purchases of natural gas from affiliates		1		2		2		4		3		3
Services provided by related parties⁽¹⁾		32		36		98		106		35		33
Services provided to related parties⁽²⁾		53		37		166		113		37		52

(1)	Includes capitalized expenditures of ~~$10~~$5 million and ~~$13~~$10 million for the three months ended ~~September 30,~~March 31, 2019 and 2018, ~~and 2017, respectively, and $27 million and $33 million for the nine months ended September 30, 2018 and 2017,~~ 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, 2018		December 31, 2017		March 31, 2019		December 31, 2018
(millions)
Other receivables⁽¹⁾	$	15	$	12	$	11	$	13
Customer receivables from related parties		1		1		—		1
Imbalances receivable from affiliates		—		1		1		1
Imbalances payable to affiliates⁽²⁾		7		—		3		13
Affiliated notes receivable⁽³⁾		17		20		15		16

(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)	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 ~~$24~~$47 million and ~~$18~~$218 million as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively. Interest charges related to Dominion Energy Gas’ total borrowings from Dominion Energy were ~~less than $1 million~~immaterial for the three ~~and nine~~ months ended ~~September 30, 2018~~March 31, 2019 and ~~2017.~~2018.

Note ~~19.~~20. Employee Benefit Plans

Dominion Energy

The components of Dominion Energy’s provision for net periodic benefit cost (credit) were as follows:

	Pension Benefits						Other Postretirement Benefits
	2019			2018			2019			2018
(millions)
Three Months Ended March 31,
Service cost	$	40		$	39		$	7		$	7
Interest cost		101			84			17		��	14
Expected return on plan assets		(177	)		(165	)		(33	)		(36	)
Amortization of prior service credit		—			—			(13	)		(13	)
Amortization of net actuarial loss		39			48			4			3
Settlements		2			—			—			—
Net periodic benefit cost (credit)	$	5		$	6		$	(18	)	$	(25	)

Pension Benefits

Other Postretirement Benefits

2018

2017

2018

2017

(millions)

Three Months Ended September 30,

Service cost

$
39

$
35

$
7

$
7

Interest cost

85

86

14

15

Expected return on plan assets

(165
)

(160
)

(36
)

(32
)
Amortization of prior service cost (credit)

—

—

(13
)

(13
)
Amortization of net actuarial loss

48

40

3

3

Settlements

—

1

—

—

Net periodic benefit cost (credit)

$
7

$
2

$
(25
)

$
(20
)
Nine Months Ended September 30,

Service cost

$
118

$
104

$
20

$
20

Interest cost

253

259

42

45

Expected return on plan assets

(498
)

(480
)

(107
)

(95
)
Amortization of prior service cost (credit)

1

1

(39
)

(38
)
Amortization of net actuarial loss

145

121

8

9

Settlements

—

2

—

—

Net periodic benefit cost (credit)

$
19

$
7

$
(76
)

$
(59
)

Voluntary Retirement Program

In March 2019, the Companies announced a voluntary retirement program to employees that meet certain age and service requirements. The Companies expect to incur a charge in the second quarter of 2019 as determinations are made concerning the number of employees that elect to participate in the program. The voluntary retirement program will not compromise safety or the Companies’ ability to comply with applicable laws and regulations. While the Companies are unable to estimate the amount, it could be material to the Companies’ results of operations and financial condition.

Employer Contributions

During the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, Dominion Energy made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion Energy expects to contribute approximately $21 million and $12 million to its defined benefit pension plans and other postretirement benefit plans through VEBAs, respectively, during the remainder of ~~2018.~~2019.

Dominion Energy Gas

The components of Dominion Energy Gas’ provision for net periodic benefit cost (credit) for employees represented by collective bargaining units were as ~~follows~~

follows:

	Pension Benefits						Other Postretirement Benefits						Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017			2019			2018			2019			2018
(millions)
Three Months Ended September 30,
Three Months Ended March 31,
Service cost	$	4		$	3		$	1		$	1		$	4		$	4		$	1		$	1
Interest cost		7			7			3			3			8			7			3			3
Expected return on plan assets		(36	)		(34	)		(7	)		(7	)		(39	)		(37	)		(7	)		(8	)
Amortization of prior service credit		—			—			(1	)		(1	)		—			—			(1	)		(1	)
Amortization of net actuarial loss		4			4			—			1			5			5			1			1
Net periodic benefit credit	$	(21	)	$	(20	)	$	(4	)	$	(3	)	$	(22	)	$	(21	)	$	(3	)	$	(4	)
Nine Months Ended September 30,
Service cost	$	13		$	11		$	3		$	3
Interest cost		21			22			8			9
Expected return on plan assets		(111	)		(105	)		(21	)		(19	)
Amortization of prior service credit		—			—			(3	)		(2	)
Amortization of net actuarial loss		14			12			2			2
Net periodic benefit credit	$	(63	)	$	(60	)	$	(11	)	$	(7	)

Employer Contributions

During the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, Dominion Energy Gas made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion Energy Gas expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs ~~for both employees represented by collective bargaining units and employees not represented by collective bargaining units,~~ during the remainder of ~~2018.~~2019.

Note ~~20.~~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	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
Power Generation	Regulated electric generation fleet	X	X
	Merchant electric generation fleet	X
Gas Infrastructure	Gas transmission and storage	X		X
	Gas distribution and storage	X		X
	Gas gathering and processing	X		X
	LNG terminalling and storage	X
	Nonregulated retail energy marketing	X
Southeast Energy	Regulated electric distribution	X
	Regulated electric transmission	X
	Regulated electric generation fleet	X
	Gas distribution and storage	X
	Nonregulated retail energy marketing	X

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.

In the ~~nine~~three months ended ~~September 30,~~March 31, 2019, Dominion Energy reported after-tax net expenses of $1.6 billion for specific items in the Corporate and Other segment, with $1.4 billion of net expenses attributable to its operating segments. In the three months ended March 31, 2018, Dominion Energy reported after-tax net expenses of ~~$253~~$238 million for specific items in the Corporate and Other segment, with ~~$188~~$218 million of net expenses attributable to its operating segments. ~~In the nine months ended September 30, 2017, Dominion Energy reported after-tax~~

The net ~~expenses of $17 million~~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 ($756 million after-tax) charge for refunds of amounts previously collected from retail electric customers of DESC for the NND Project, attributable to Southeast Energy;

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

A $198 million tax charge for $264 million of income tax-related regulatory assets acquired in the ~~Corporate and Other segment, with $1 million of net expenses~~SCANA Combination for which Dominion Energy committed to forgo recovery, attributable to ~~its operating segments.~~Southeast Energy;

A $169 million ($127 million after-tax) charge for a settlement agreement of a DESC ratepayer class action lawsuit, attributable to Southeast Energy;

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;

$106 million ($81 million after-tax) of merger and integration-related costs associated with the SCANA Combination, attributable to Southeast Energy; and

A $105 million ($79 million after-tax) charge for property, plant and equipment acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery, attributable to Southeast Energy; partially offset by

•	A $253 million ($189 million after-tax) net gain related to investments in nuclear decommissioning trust funds, attributable to Power Generation; 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~~$43 million ($~~121~~32 million after-tax) ~~increased net investment earnings~~loss on investments held in 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.~~

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.

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

	Power Delivery		Power Generation		Gas Infrastructure		Corporate and Other			Adjustments/ Eliminations			Consolidated Total		Power Delivery		Power Generation		Gas Infrastructure		Southeast Energy		Corporate and Other			Adjustments/ Eliminations			Consolidated Total
(millions)
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
Three Months Ended September 30, 2017
Three Months Ended March 31, 2019
Total revenue from external customers	$	580	$	1,931	$	459	$	3		$	206		$	3,179	$	598	$	1,745	$	1,373	$	1,182	$	(1,040	)	$	—		$	3,858
Intersegment revenue		4		3		204		150			(361	)		—		6		4		26		—		184			(220	)		—
Total operating revenue		584		1,934		663		153			(155	)		3,179		604		1,749		1,399		1,182		(856	)		(220	)		3,858
Net income (loss) attributable to Dominion Energy		138		369		187		(29	)		—			665		155		308		359		132		(1,634	)		—			(680	)
Nine Months Ended September 30, 2018
Three Months Ended March 31, 2018
Total revenue from external customers	$	1,687	$	5,516	$	2,972	$	(210	)	$	40		$	10,005	$	563	$	1,860	$	1,222			$	(207	)	$	28		$	3,466
Intersegment revenue		17		8		21		505			(551	)		—		6		2		6				175			(189	)		—
Total operating revenue		1,704		5,524		2,993		295			(511	)		10,005		569		1,862		1,228				(32	)		(161	)		3,466
Net income (loss) attributable to Dominion Energy		464		1,038		840		(536	)		—			1,806		156		348		327				(328	)		—			503
Nine Months Ended September 30, 2017
Total revenue from external customers	$	1,664	$	5,091	$	1,949	$	12		$	660		$	9,376
Intersegment revenue		16		8		645		451			(1,120	)		—
Total operating revenue		1,680		5,099		2,594		463			(460	)		9,376
Net income (loss) attributable to Dominion Energy		390		870		613		(186	)		—			1,687

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 that are not included in profit measures evaluated by executive management in assessing the segments' performance or in allocating resources.

In the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, Virginia Power reported after-tax net expenses of ~~$229~~$344 million for specific items in the Corporate and Other segment, with ~~$226~~$324 million of net expenses attributable to its operating segments. In the ~~nine~~three months ended ~~September 30, 2017,~~March 31, 2018, Virginia Power reported after-tax net expenses of $7$197 million for specific items in the Corporate and Other segment, ~~all~~with $189 million of ~~which was~~net expenses attributable to its operating segments.

The net expense for specific items attributable to Virginia Power’s operating segments 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;

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

A $29 million ($22 million after-tax) charge related to a portion of rate adjustment clauses for excess deferred taxes which are probable of being returned to customers, attributable to:

Power Generation ($19 million after-tax); and

Power Delivery ($3 million after-tax), partially offset by

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).

~~An $81~~A $31 million ($6023 million after-tax) charge for storm damage and service restoration costs associated ~~primarily~~ with ~~the asset retirement obligations for ash ponds and landfills at certain utility generation facilities in connection with the enactment of~~Winter Storm Riley affecting its Virginia ~~legislation in April 2018~~service territory, attributable to Power ~~Generation.~~

~~The net expense for specific items attributable to Virginia Power’s operating segments in 2017 primarily related to the impact of the following item which was attributable to Power Delivery:~~

~~A $16 million ($10 million after-tax) charge arising from a proposed customer settlement.~~Delivery.

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

Power
Delivery

Power
Generation

Corporate
and Other

Consolidated
Total

(millions)

Three Months Ended September 30, 2018

Operating revenue

$
595

$
1,637

$
—

$
2,232

Net income

163

347

10

520

Three Months Ended September 30, 2017

Operating revenue

$
580

$
1,574

$
—

$
2,154

Net income

137

314

8

459

Nine Months Ended September 30, 2018

Operating revenue

$
1,686

$
4,338

$
(215
)

$
5,809

Net income (loss)

462

796

(215
)

1,043

Nine Months Ended September 30, 2017

Operating revenue

$
1,670

$
4,062

$
—

$
5,732

Net income

387

735

11

1,133

	Power Delivery		Power Generation		Corporate and Other			Consolidated Total
(millions)
Three Months Ended March 31, 2019
Operating revenue	$	598	$	1,396	$	(29	)	$	1,965
Net income (loss)		154		204		(338	)		20
Three Months Ended March 31, 2018
Operating revenue	$	563	$	1,400	$	(215	)	$	1,748
Net income (loss)		154		222		(192	)		184

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 both the ~~nine~~three months ended ~~September 30,~~March 31, 2019 and 2018, Dominion Energy Gas reported ~~after-tax net expenses~~an immaterial amount of ~~$100 million for~~ specific items in the Corporate and Other segment, with $99 million of net expenses attributable to its operating segment. In the nine months ended September 30, 2017, Dominion Energy Gas reported after-tax net expenses of $9 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segment.

~~The net expense for specific items in 2018 was due to a $124 million ($88 million after-tax) charge for disallowance of FERC-regulated plant.~~

~~The net expense for specific items in 2017 was due to a $15 million ($9 million after-tax) charge to write-off the balance of a regulatory asset no longer considered probable of recovery.~~

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

	Gas Infrastructure		Corporate and Other			Consolidated Total		Gas Infrastructure		Corporate and Other			Consolidated Total
(millions)
Three Months Ended September 30, 2018
Three Months Ended March 31, 2019
Operating revenue	$	423	$	—		$	423	$	511	$	—		$	511
Net income (loss)		146		(10	)		136		119		(3	)		116
Three Months Ended September 30, 2017
Three Months Ended March 31, 2018
Operating revenue	$	401	$	—		$	401	$	526	$	—		$	526
Net income (loss)		121		(4	)		117		167		(1	)		166
Nine Months Ended September 30, 2018
Operating revenue	$	1,408	$	—		$	1,408
Net income (loss)		421		(104	)		317
Nine Months Ended September 30, 2017
Operating revenue	$	1,313	$	—		$	1,313
Net income (loss)		318		(16	)		302

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 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 and changes in water temperatures and availability that can cause outages and property damage to facilities;

Federal, state and local legislative and regulatory developments, including changes in federal and state tax laws and ~~regulations, including provisions of the 2017 Tax Reform Act that became effective in January 2018;~~regulations;

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;

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;

•

~~Risks associated with~~Unplanned outages at facilities in which 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;~~Companies have an ownership interest;

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

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;

Counterparty credit and performance risk;

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

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

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 interest rates or foreign currency exchange rates;

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

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

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

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

Impacts of acquisitions, including the recently completed SCANA Combination, divestitures, transfers of assets to joint ventures ~~or Dominion Energy Midstream~~ and retirements of assets based on asset portfolio reviews;

The expected timing and likelihood of completion of the proposed acquisition of SCANA, including the ability to obtain the requisite approvals of regulators and the terms and conditions of any regulatory approvals;

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

Changes in rules for regional transmission organizations and independent system operators in which Dominion Energy and Virginia Power participate, including changes in rate designs, changes in FERC’s interpretation of market rules and new and evolving capacity models;

Political and economic conditions, including inflation and deflation;

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

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;

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 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 operating, maintenance and construction costs;

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 or intervention in such projects;

•

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

~~Adverse outcomes in litigation matters or regulatory proceedings; and~~

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.

Additionally, other risks that could cause actual results to differ from predicted results are set forth in Item 1A. Risk Factors in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017.~~2018.

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 30, 2018,~~March 31, 2019, 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018. 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:

2018

2017

$ Change

(millions, except EPS)

Third Quarter

Net income attributable to Dominion Energy

$
854

$
665

$
189

Diluted EPS

1.30

1.03

0.27

Year-to-Date

Net income attributable to Dominion Energy

$
1,806

$
1,687

$
119

Diluted EPS

2.77

2.66

0.11


	2019			2018		$ Change
(millions, except EPS)
First Quarter
Net income (loss) attributable to Dominion Energy	$	(680	)	$	503	$	(1,183	)
Diluted EPS		(0.86	)		0.77		(1.63	)

Overview

~~Third~~First Quarter ~~2018~~2019 vs. ~~2017~~2018

Net income attributable to Dominion Energy ~~increased 28%,~~decreased $1.2 billion, primarily due to ~~increased~~charges for refunds of amounts previously collected from retail electric customers of DESC for the NND Project, certain regulatory assets and property, plant and equipment acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery, a settlement agreement of a DESC ratepayer class action lawsuit and the planned early retirement of certain Virginia Power electric generation facilities and automated meter reading infrastructure. These decreases were partially offset by an increase in net investment earnings on nuclear decommissioning trust funds and the ~~commencement~~absence of ~~commercial operations of the Liquefaction Project.~~

~~Year-To-Date 2018 vs. 2017~~

Net income attributable to Dominion Energy increased 7%, primarily due to the commencement of commercial operations of the Liquefaction Project and increased net investment earnings on nuclear decommissioning trust funds. These increases were partially offset by a charge associated with Virginia legislation enacted in March 2018.

Analysis of Consolidated Operations

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

	Third Quarter							Year-To-Date								First Quarter
	2018		2017		$ Change			2018		2017			$ Change			2019		2018		$ Change
(millions)
Operating revenue	$	3,451	$	3,179	$	272		$	10,005	$	9,376		$	629		$	3,858	$	3,466	$	392
Electric fuel and other energy-related purchases		761		638		123			2,128		1,711			417			791		744		47
Purchased (excess) electric capacity		50		21		29			87		(8	)		95
Purchased electric capacity																	39		14		25
Purchased gas		5		24		(19	)		409		441			(32	)		730		340		390
Net revenue		2,635		2,496		139			7,381		7,232			149			2,298		2,368		(70	)
Other operations and maintenance		782		697		85			2,585		2,308			277			1,002		795		207
Depreciation, depletion and amortization		526		485		41			1,487		1,421			66			651		498		153
Other taxes		177		162		15			542		519			23			292		199		93
Impairment of assets and other charges																	835		1		834
Other income		373		121		252			658		391			267			388		100		288
Interest and related charges		378		305		73			1,053		905			148			469		314		155
Income tax expense		262		272		(10	)		485		683			(198	)		114		135		(21	)
Noncontrolling interests		29		31		(2	)		81		100			(19	)		3		23		(20	)

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

~~Third~~First Quarter ~~2018~~2019 vs. ~~2017~~2018

Net revenue ~~increased 6%~~decreased 3%, primarily reflecting:

A ~~$181~~$390 million net decrease from the SCANA Combination, due to a $1.0 billion charge for refunds of amounts previously collected from retail electric customers of DESC for the NND Project, partially offset by operations acquired ($617 million);

A $47 million decrease from the absence of certain merchant generation facilities sold in 2018;

A $33 million decrease in sales to Virginia Power retail customers from a decrease in heating degree days;

A $16 million decrease due to the annual PJM capacity performance market effective June 2018; and

A $15 million decrease in services performed for Atlantic Coast Pipeline.

These decreases were partially offset by:

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; and

A $194 million increase due to commencement of commercial operations of the Liquefaction ~~Project,~~Facility, including terminalling services provided to the export customers ($~~175~~174 million) and regulated gas transportation contracts to serve the export customers ($1921 million)., ~~partially offset by credits associated with the start-up phase of the Liquefaction Project ($13 million);~~

~~A $36 million increase in sales to electric utility retail customers from an increase in cooling degree days;~~

~~A $23 million increase due to growth projects placed in service, other than the Liquefaction Project;~~

~~A $22 million increase due to favorable pricing at merchant generation facilities; and~~

~~An $18 million increase in services performed for Atlantic Coast Pipeline; partially offset by~~

~~A $68 million decrease for regulated electric generation and electric and gas distribution operations as a result of the 2017 Tax Reform Act;~~

~~A $28 million decrease in rate adjustment clauses associated with electric utility operations, which includes the impacts of the 2017 Tax Reform Act; and~~

~~A $16 million increase in net electric capacity expense related to the annual PJM capacity performance market effective June 2018.~~

Other operations and maintenance increased ~~13%~~26%, primarily reflecting:

~~An $18~~A $184 million increase from the operations acquired in the SCANA Combination;

Merger and integration-related costs associated with the SCANA Combination ($111 million);

The absence of gains related to agreements to convey shale development rights under natural gas storage fields ($44 million); and

A $20 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;~~

~~An $18 million increase in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income;~~

~~A $17 million increase in salaries, wages and benefits; and~~

~~A $14 million increase in storm damage and service restoration costs.~~

~~Other income~~ increased $252 million, primarily reflecting an increase in net investment earnings on nuclear decommissioning trust funds ($148 million) and a gain on the sale of Dominion Energy’s 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership ($87 million).

~~Interest and related charges~~ increased 24%, primarily due to the absence of capitalization of interest expense associated with the Liquefaction Project upon completion of construction ($38 million), higher long-term debt interest expense resulting from net debt issuances in 2018 ($12 million) and associated variable interest rates ($9 million) and increases in the carrying amount of commercial paper and associated interest rates ($9 million).

~~Income tax expense~~ ~~decreased 4%, primarily due to the 2017 Tax Reform Act ($109 million), partially offset by higher pre-tax income ($62 million) and lower renewable energy investment tax credits ($46 million).~~

~~Year-To-Date 2018 vs. 2017~~

~~Net revenue~~ ~~increased 2%, primarily reflecting:~~

~~A $324 million increase due to commencement of commercial operations of the Liquefaction Project, including terminalling services provided to the export customers ($334 million) and~~ ~~regulated gas transportation contracts to serve the export customers ($38 million)~~, ~~partially offset by credits associated with the start-up phase of the Liquefaction Project ($48 million);~~

An increase in sales to electric utility retail customers from an increase in heating degree days during the heating season of 2018 ($69 million) and an increase in cooling degree days during the cooling season of 2018 ($69 million);

~~A $115 million increase due to favorable pricing at merchant generation facilities;~~

~~An $87 million increase due to growth projects placed in service, other than the Liquefaction Project;~~

~~A $63 million increase in services performed for Atlantic Coast Pipeline; and~~

A $27 million increase in sales to electric utility retail customers due to customer growth ($39 million), partially offset by changes in customer usage and other factors ($12 million); partially offset by

~~A $215 million charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers;~~

~~A $203 million decrease for regulated electric generation and electric and gas distribution operations as a result of the 2017 Tax Reform Act;~~

A $77 million increase in net electric capacity expense related to the annual PJM capacity performance market effective June 2017 ($112 million) and the annual PJM capacity performance market effective June 2018 ($22 million), partially offset by a benefit related to non-utility generators ($57 million); and

~~A $70 million decrease in rate adjustment clauses associated with electric utility operations, which includes the impacts of the 2017 Tax Reform Act.~~

~~Other operations and maintenance~~ ~~increased 12%, primarily reflecting:~~

~~A $135 million increase due to a charge for disallowance of FERC-regulated plant;~~

~~An $81 million increase due to a charge~~ ~~associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018;~~

~~A $62 million increase in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income;~~

~~A $49 million increase in storm damage and service restoration costs;~~

~~A $45 million increase in salaries, wages and benefits; and~~

~~A $34 million increase in operating expenses from the commercial operations of the Liquefaction Project~~Facility and costs associated with regulated gas transportation contracts to serve the export customers; partially offset by

A ~~$68 million decrease~~benefit from the revision of future ash pond and landfill closure costs as a ~~reduction~~result of Virginia legislation enacted in ~~planned outage days at certain merchant and utility generation facilities; and~~March 2019 ($113 million);

A ~~$55~~$25 million decrease ~~from gains related~~in storm damage and service restoration costs at Virginia Power, primarily due to ~~agreements to convey shale development rights under natural gas storage fields.~~the absence of Winter Storm Riley ($31 million); and

•	A $15 million decrease in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income.

Depreciation, depletion and amortizationincreased 5%31%, primarily due to property, plant and equipment acquired in the SCANA Combination ($128 million) and an increase from various growth projects being placed into service ($~~142~~51 million), including the Liquefaction ~~Project~~Facility ($~~49 million), partially offset by revised depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements ($53~~28 million).

Other taxes increased 47%, primarily due to the SCANA Combination.

Impairment of assets and other charges increased $834 million, primarily due to a $368 million charge related to the early retirement of certain Virginia Power electric generation facilities, a $169 million charge for a settlement agreement of a DESC ratepayer class action lawsuit, a $160 million charge related to Virginia Power’s planned early retirement of certain automated meter reading infrastructure and a $105 million charge for property, plant and equipment acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery.

Other income increased ~~68%,~~$288 million, primarily reflecting an increase in net investment earnings on nuclear decommissioning trust ~~funds ($146 million) and a gain on the sale of Dominion Energy’s 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership ($87 million).~~funds.

Interest and related charges increased ~~16%~~49%, primarily due to debt acquired in the SCANA Combination ($93 million), the absence of capitalization of interest expense associated with the Liquefaction ~~Project~~Facility upon completion of construction ($7142 million), and higher long-term debt interest expense resulting from net debt issuances in 2018 ~~and 2017~~ ($~~38 million) and increases in the carrying amount of commercial paper and associated interest rates ($22~~19 million).

Income tax expensedecreased ~~29%~~16%, primarily due to ~~the 2017 Tax Reform Act ($279 million) and~~ lower pre-tax income ($34220 million), partially offset by ~~lower renewable energy investment tax credits~~a charge for certain income tax-related regulatory assets acquired in the SCANA Combination for which Dominion Energy committed to forgo recovery ($~~119~~198 million).

Noncontrolling interests decreased $20 million, primarily due to the acquisition of the public interest in Dominion Energy Midstream in January 2019.

Segment Results of Operations

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

	Net Income attributable to Dominion Energy									Diluted EPS									Net Income attributable to Dominion Energy									Diluted EPS
	2018			2017			$ Change			2018			2017			$ Change			2019			2018			$ Change			2019			2018			$ Change
(millions, except EPS)
Third Quarter
First Quarter
Power Delivery	$	163		$	138		$	25		$	0.25		$	0.21		$	0.04		$	155		$	156		$	(1	)	$	0.19		$	0.24		$	(0.05	)
Power Generation		414			369			45			0.63			0.57			0.06			308			348			(40	)		0.39			0.54			(0.15	)
Gas Infrastructure		264			187			77			0.40			0.29			0.11			359			327			32			0.45			0.50			(0.05	)
Southeast Energy																				132			—			132			0.17			—			0.17
Primary operating segments		841			694			147			1.28			1.07			0.21			954			831			123			1.20			1.28			(0.08	)
Corporate and Other		13			(29	)		42			0.02			(0.04	)		0.06			(1,634	)		(328	)		(1,306	)		(2.06	)		(0.51	)		(1.55	)
Consolidated	$	854		$	665		$	189		$	1.30		$	1.03		$	0.27		$	(680	)	$	503		$	(1,183	)	$	(0.86	)	$	0.77		$	(1.63	)

Year-To-Date
Power Delivery	$	464		$	390		$	74		$	0.71		$	0.62		$	0.09
Power Generation		1,038			870			168			1.59			1.37			0.22
Gas Infrastructure		840			613			227			1.29			0.97			0.32
Primary operating segments		2,342			1,873			469			3.59			2.96			0.63
Corporate and Other		(536	)		(186	)		(350	)		(0.82	)		(0.30	)		(0.52	)
Consolidated	$	1,806		$	1,687		$	119		$	2.77		$	2.66		$	0.11

Power Delivery

Presented below are selected operating statistics related to Power Delivery’s operations:

	Third Quarter							Year-To-Date							First Quarter
	2018		2017		% Change			2018		2017		% Change			2019		2018		% Change
Electricity delivered (million MWh)		24.0		23.0		4	%		67.0		63.2		6	%		21.8		22.1		(1	)%
Degree days (electric distribution service area):
Cooling		1,271		1,124		13			1,890		1,698		11			5		8		(38	)
Heating		—		2		(100	)		2,306		1,825		26			1,892		2,022		(6	)
Average electric distribution customer accounts (thousands)⁽¹⁾		2,603		2,576		1			2,597		2,570		1			2,617		2,591		1

(1)	Period average.

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

	Third Quarter 2018 vs. 2017 Increase (Decrease)						Year-To-Date 2018 vs. 2017 Increase (Decrease)						First Quarter 2019 vs. 2018 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	6		$	0.01		$	28		$	0.04		$	(8	)	$	(0.01	)
Other		21			0.03			37			0.06			3			—
Storm damage and service restoration		(8	)		(0.01	)		(12	)		(0.02	)
Rate adjustment clause equity return		6			0.01			11			0.02			12			0.02
Other		—			—			10			0.01			(8	)		(0.01	)
Share dilution		—			—			—			(0.02	)		—			(0.05	)
Change in net income contribution	$	25		$	0.04		$	74		$	0.09		$	(1	)	$	(0.05	)

Power Generation

Presented below are selected operating statistics related to Power Generation’s operations:

	Third Quarter							Year-To-Date							First Quarter
	2018		2017		% Change			2018		2017		% Change			2019		2018		% Change
Electricity supplied (million MWh):
Utility		24.0		23.1		4	%		67.1		64.7		4	%		21.9		22.3		(2	)%
Merchant		8.1		7.9		3			23.1		22.7		2			5.2		7.3		(29	)
Degree days (electric utility service area):
Cooling		1,271		1,124		13			1,890		1,698		11			5		8		(38	)
Heating		—		2		(100	)		2,306		1,825		26			1,892		2,022		(6	)

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

	Third Quarter 2018 vs. 2017 Increase (Decrease)						Year-To-Date 2018 vs. 2017 Increase (Decrease)						First Quarter 2019 vs. 2018 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
Merchant generation margin	$	15		$	0.02		$	109		$	0.17		$	(10	)	$	(0.01	)
Regulated electric sales:
Weather	15				0.02			56		0.09				(16	)		(0.03	)
Other		(6	)		(0.01	)		(13	)		(0.02	)		(4	)		(0.01	)
Electric capacity		(11	)		(0.02	)		(49	)		(0.08	)		(11	)		(0.02	)
Planned outage costs		1			—			41			0.07
Depreciation and amortization		6			0.01			16			0.03
Renewable energy investment tax credits		4			0.01			(51	)		(0.08	)
2017 Tax Reform Act impacts		12			0.02			44			0.07
Sale of certain merchant generation facilities														(14	)		(0.02	)
Other		9			0.02			15			0.02			15			0.02
Share dilution		—			(0.01	)		—			(0.05	)		—			(0.08	)
Change in net income contribution	$	45		$	0.06		$	168		$	0.22		$	(40	)	$	(0.15	)

Gas Infrastructure

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

	Third Quarter							Year-To-Date							First Quarter
	2018		2017		% Change			2018		2017		% Change			2019		2018		% Change
Gas distribution throughput (bcf):
Sales		9		10		(10	%)		85		85	-%				64		57	12%
Transportation		153		143		7			525		469		12			223		214		4
Heating degree days (gas distribution service area):
Eastern region		48		66		(27	)		3,633		2,940		24			2,915		2,915		—
Western region		18		131		(86	)		2,518		3,024		(17	)		2,570		2,095		23
Average gas distribution customer accounts (thousands)⁽¹⁾:
Sales		1,253		1,234		2			1,254		1,234		2			1,272		1,257		1
Transportation		1,092		1,082		1			1,097		1,089		1			1,111		1,098		1
Average retail energy marketing customer accounts (thousands)⁽¹⁾		867		1,463		(41	)		864		1,447		(40	)		376		862		(56	)

(1)Period average.

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

	Third Quarter 2018 vs. 2017 Increase (Decrease)						Year-To-Date 2018 vs. 2017 Increase (Decrease)						First Quarter 2019 vs. 2018 Increase (Decrease)
	Amount			EPS			Amount			EPS			Amount			EPS
(millions, except EPS)
2017 Tax Reform Act impacts	$	24		$	0.03		$	91		$	0.14
Cove Point export contracts													$	112		$	0.17
Noncontrolling interest⁽¹⁾														14			0.02
Interest expense, net														(50	)		(0.07	)
Assignment of shale development rights		3			—			33			0.05			(32	)		(0.05	)
State legislative change		—			—			18			0.03
Transportation and storage growth projects		9			0.02			27			0.04
Cove Point export contracts		94			0.15			168			0.27
Cove Point import contracts		—			—			(12	)		(0.02	)
Interest expense, net		(31	)		(0.05	)		(59	)		(0.09	)
Other		(22	)		(0.03	)		(39	)		(0.06	)		(12	)		(0.02	)
Share dilution		—			(0.01	)		—			(0.04	)		—			(0.10	)
Change in net income contribution	$	77		$	0.11		$	227		$	0.32		$	32		$	(0.05	)

(1)Reflects the acquisition of the public interest in Dominion Energy Midstream in January 2019.

Southeast Energy

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

	First Quarter
	2019
Electricity delivered (million MWh)		5.1
Electricity supplied (million MWh)		5.2
Degree days (electric distribution service area):
Cooling		—
Heating		660
Average electric distribution customer accounts (thousands)⁽¹⁾	734
Gas distribution throughput (bcf):
Sales	42
Transportation	17
Heating degree days (gas distribution service area)		759
Average gas distribution customer accounts (thousands)⁽¹⁾	963
Average retail energy marketing customer accounts (thousands)⁽¹⁾	423

(1)Period average.

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

	First Quarter 2019 vs. 2018 Increase
	Amount		EPS
(millions, except EPS)
SCANA Combination	$	132	$	0.17
Change in net income contribution	$	132	$	0.17

Corporate and Other

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

Third Quarter

Year-To-Date

2018

2017

$ Change

2018

2017

$ Change

(millions, except EPS)

Specific items attributable to operating segments

$
122

$
—

$
122

$
(188
)

$
(1
)

$
(187
)
Specific items attributable to Corporate and Other
segment

(26
)

(7
)

(19
)

(65
)

(16
)

(49
)
Total specific items

96

(7
)

103

(253
)

(17
)

(236
)
Other corporate operations:

Renewable energy investment tax credits

(1
)

52

(53
)

11

79

(68
)
2017 Tax Reform Act impacts

(21
)

—

(21
)

(60
)

—

(60
)
Interest expense, net

(93
)

(85
)

(8
)

(265
)

(258
)

(7
)
Other

32

11

21

31

10

21

Total other corporate operations

(83
)

(22
)

(61
)

(283
)

(169
)

(114
)
Total net expense

$
13

$
(29
)

$
42

$
(536
)

$
(186
)

$
(350
)
EPS impact

$
0.02

$
(0.04
)

$
0.06

$
(0.82
)

$
(0.30
)

$
(0.52
)

	First Quarter
	2019			2018			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	(1,375	)	$	(218	)	$	(1,157	)
Specific items attributable to Corporate and Other segment		(178	)		(20	)		(158	)
Total specific items		(1,553	)		(238	)		(1,315	)
Other corporate operations⁽¹⁾		(81	)		(90	)		9
Total net expense	$	(1,634	)	$	(328	)	$	(1,306	)
EPS impact	$	(2.06	)	$	(0.51	)	$	(1.55	)

(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 segments' performance or in allocating resources. See Note 2021 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							First Quarter
	2018		2017		$ Change		2018		2017		$ Change			2019		2018		$ Change
(millions)
Net income	$	520	$	459	$	61	$	1,043	$	1,133	$	(90	)	$	20	$	184	$	(164	)

Overview

~~Third~~First Quarter ~~2018~~2019 vs. ~~2017~~

~~Net income increased 13%, primarily due an increase in cooling degree days in the service territory.~~

~~Year-To-Date~~ 2018 ~~vs. 2017~~

Net income decreased 8%89%, primarily due to charges associated with the planned early retirement of certain electric generation facilities and automated meter reading infrastructure. This decrease was partially offset by the absence of a charge associated with Virginia legislation enacted in March 2018 and a ~~charge associated primarily with~~benefit from the revision of future ash pond and landfill closure costs ~~in connection with the enactment~~as a result of Virginia legislation signed in ~~April 2018 and an increase in net electric capacity expense, partially offset by an increase in heating and cooling degree days in the service territory.~~March 2019.

Analysis of Consolidated Operations

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

	Third Quarter							Year-To-Date								First Quarter
	2018		2017		$ Change			2018		2017			$ Change			2019		2018		$ Change
(millions)
Operating revenue	$	2,232	$	2,154	$	78		$	5,809	$	5,732		$	77		$	1,965	$	1,748	$	217
Electric fuel and other energy-related purchases		648		549		99			1,747		1,414			333			596		591		5
Purchased (excess) electric capacity		50		21		29			87		(8	)		95
Purchased electric capacity																	33		14		19
Net revenue		1,534		1,584		(50	)		3,975		4,326			(351	)		1,336		1,143		193
Other operations and maintenance		404		373		31			1,242		1,126			116			279		399		(120	)
Depreciation and amortization		295		288		7			839		854			(15	)		304		297		7
Other taxes		79		76		3			241		233			8			85		83		2
Impairment of assets and other charges																	546		—		546
Other income		25		13		12			49		57			(8	)		37		3		34
Interest and related charges		130		128		2			388		373			15			135		132		3
Income tax expense		131		273		(142	)		271		664			(393	)		4		51		(47	)

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

~~Third~~First Quarter ~~2018~~2019 vs. ~~2017~~2018

Net revenue ~~decreased 3%~~increased 17%, primarily reflecting:

~~A $49~~The absence of a $215 million ~~decrease for regulated generation and distribution operations as a result~~charge associated with Virginia legislation enacted in March 2018 that required one-time rate credits of ~~the 2017 Tax Reform Act;~~certain amounts to utility customers;

A ~~$28~~$14 million ~~decrease~~increase from rate adjustment ~~clauses, which includes the impacts of the 2017 Tax Reform Act~~;clauses; partially offset by

A $33 million decrease in sales to retail customers from a decrease in heating degree days; and

A $16 million increase in net electric capacity expense related to the annual PJM capacity performance market effective June ~~2018; partially offset by~~

~~A $36 million increase in sales to retail customers from an increase in cooling degree days; and~~

•	~~A $14 million increase in sales to retail customers due to customer growth.~~

~~Other operations and maintenance~~ ~~increased 8%, primarily reflecting:~~

~~A $14 million increase due to storm damage and service restoration costs; and~~

~~An $11 million increase due to the inclusion of security expenses associated with interim storage of spent nuclear fuel in base rates effective August~~ 2018.

~~Other income~~ ~~increased 92%, primarily due to higher realized gains (including investment income) on nuclear decommissioning trust funds ($17 million).~~

~~Income tax expense~~ ~~decreased 52%, primarily due to the 2017 Tax Reform Act ($100 million) and lower pre-tax income ($28 million).~~

~~Year-To-Date 2018 vs. 2017~~

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

~~A $215 million charge associated with Virginia legislation enacted in March 2018 that requires one-time rate credits of certain amounts to utility customers;~~

~~A $140 million decrease for regulated generation and distribution operations as a result of the 2017 Tax Reform Act;~~

~~A $70 million decrease from rate adjustment clauses, which includes the impacts of the 2017 Tax Reform Act; partially offset by~~

An increase in sales to retail customers from an increase in heating degree days during the heating season of 2018 ($69 million) and an increase in cooling degree days during the cooling season of 2018 ($69 million); and

~~A $27 million increase in sales to retail customers due to customer growth ($39 million),partially offset by changes in customer usage and other factors ($12 million).~~

Other operations and maintenance ~~increased 10%~~decreased 30%, primarily reflecting:

~~An $81 million increase due to a charge~~ ~~associated primarily with~~A benefit from the revision of future ash pond and landfill closure costs ~~in connection with the enactment~~as a result of Virginia legislation enacted in ~~April 2018;~~March 2019 ($113 million);

A ~~$49~~$25 million ~~increase due to~~decrease in storm damage and service restoration ~~costs; and~~

~~An $11 million increase~~costs, primarily due to the ~~inclusion~~absence of ~~security expenses associated with interim storage of spent nuclear fuel in base rates effective August 2018,~~Winter Storm Riley ($31 million); partially offset by

A ~~$26~~$10 million ~~decrease from~~increase in certain ~~fewer planned outage days at certain generation facilities.~~electric transmission-related expenditures. These expenses are primarily recovered through state and FERC rates and do not impact net income.

~~Depreciation~~Impairment of assets and ~~amortization~~other charges ~~decreased 2%,~~increased $546 million, primarily due to ~~revised depreciation rates~~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 and a $17 million charge to write-off the balance of a regulatory asset for ~~regulated nuclear plants to comply with the~~which Virginia ~~Commission requirements ($53 million), partially offset by various growth projects being placed into service ($39 million).~~Power is no longer seeking recovery.

Other income ~~decreased 14%,~~increased $34 million, primarily related to the electric transmission tower rental portfolio, including the absence of the assignment of such amounts to Vertical Bridge Towers II, LLC, ($16 million), the absence of interest income associated with the settlement of state income tax refund claims ($11 million), and lower tax recoveries associated with contributionsreflecting an increase in ~~aid of construction ($4 million), partially offset by higher realized gains (including~~net investment ~~income)~~earnings on nuclear decommissioning trust ~~funds ($13 million) and the absence of a charge associated with a customer settlement ($16 million).~~

~~Income tax expense~~ ~~decreased 59%, primarily due to the 2017 Tax Reform Act ($198 million) and lower pre-tax income ($169 million).~~funds.

Income tax expense decreased 92%, primarily due to lower pre-tax income.

Dominion Energy Gas

Results of Operations

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

	Third Quarter						Year-To-Date						First Quarter
	2018		2017		$ Change		2018		2017		$ Change		2019		2018		$ Change
(millions)
Net income	$	136	$	117	$	19	$	317	$	302	$	15	$	116	$	166	$	(50	)

Overview

~~Third~~First Quarter ~~2018~~2019 vs. ~~2017~~2018

Net income ~~increased 16%~~decreased 30%, primarily due to ~~regulated natural gas transmission activities from growth projects placed into service.~~

~~Year-To-Date 2018 vs. 2017~~

~~Net income increased 5%, primarily due~~the absence of gains related to ~~regulated natural gas transmission activities from growth projects placed into service, impacts of the 2017 Tax Reform Act and an increase in gains from~~ agreements to convey shale development rights ~~underneath several~~under natural gas storage ~~fields, partially offset by a charge for disallowance of FERC-regulated plant.~~fields.

Analysis of Consolidated Operations

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

	Third Quarter								Year-To-Date							First Quarter
	2018			2017		$ Change			2018		2017		$ Change			2019		2018			$ Change
(millions)
Operating revenue	$	423		$	401	$	22		$	1,408	$	1,313	$	95		$	511	$	526		$	(15	)
Purchased (excess) gas		(7	)		19		(26	)		22		100		(78	)
Purchased gas																	40		29			11
Other energy-related purchases		26			4		22			88		11		77			26		31			(5	)
Net revenue		404			378		26			1,298		1,202		96			445		466			(21	)
Other operations and maintenance		116			94		22			583		440		143			183		190			(7	)
Depreciation and amortization		61			57		4			173		167		6			62		59			3
Other taxes		45			42		3			152		139		13			64		60			4
Gains on sales of assets																	—		(44	)		44
Earnings from equity method investee		4			4		—			18		15		3			6		9			(3	)
Other income		34			27		7			99		79		20			34		33			1
Interest and related charges		28			25		3			79		72		7			26		25			1
Income tax expense		56			74		(18	)		111		176		(65	)		34		52			(18	)

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

~~Third~~First Quarter ~~2018~~2019 vs. ~~2017~~2018

Net revenue~~increased 7%~~ decreased 5%, primarily reflecting:

A ~~$19~~$15 million ~~increase due to regulated natural gas transmission growth projects placed in service;~~

~~An $18 million increase~~decrease in services performed for Atlantic Coast Pipeline; ~~and~~

A $4$13 million increase in net fuel costs; partially offset by

A $6 million increase in PIR program ~~revenues; partially offset by~~

~~An $8 million decrease for regulated distribution operations as a result of the 2017 Tax Reform Act; and~~

~~A $4 million decrease from scheduled declines in certain DETI contracts.~~revenues.

Other operations and maintenance~~increased 23%~~ decreased 4%, primarily ~~reflecting:~~

~~An $18 million increase~~reflecting a decrease in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net ~~income; and~~income.

•	~~An $11 million increase in salaries, wages and benefits; partially offset by~~

~~A $5~~

Gains on sales of assets decreased $44 million ~~decrease from~~due to the absence of gains related to agreements to convey shale development rights under natural gas storage fields.

~~Other income~~ ~~increased 26%, primarily due to a decrease in the non-service components of pension and other postretirement employee benefit credits capitalized to property, plant and equipment in 2018.~~

~~Interest and related charges~~ increased 12%, primarily due to higher interest expense on long-term debt due to an issuance in the second quarter 2018 and associated interest rates ($5 million), partially offset by an increase in deferred carrying costs ($2 million).

~~Income tax expense~~ ~~decreased 24%, primarily due to the 2017 Tax Reform Act.~~

~~Year-To-Date 2018 vs. 2017~~

~~Net revenue~~ ~~increased 8%, primarily reflecting:~~

~~A $63 million increase in services performed for Atlantic Coast Pipeline;~~

~~A $55 million increase due to regulated natural gas transmission growth projects placed in service; and~~

~~A $15 million increase in PIR program revenues; partially offset by~~

~~A $27 million decrease for regulated distribution operations as a result of the 2017 Tax Reform Act; and~~

~~An $18 million decrease from scheduled declines in certain DETI contracts.~~

~~Other operations and maintenance~~ ~~increased 33%, primarily reflecting:~~

~~A $135 million increase due to a charge for disallowance of FERC-regulated plant; and~~

~~A $62 million increase in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income; partially offset by~~

~~A $55 million decrease from gains related to agreements to convey shale development rights under natural gas storage fields; and~~

~~A $15 million decrease from the absence of a charge to write-off the balance of a regulatory asset no longer considered probable of recovery.~~

Earnings from equity method investee~~increased 20%~~ decreased 33%, primarily due to ~~higher~~lower earnings from unsubscribed capacity as a result of ~~an increase~~a decrease in heating degree days at Iroquois.

~~Other income~~ increased 25%, primarily due to a decrease in the non-service components of pension and other postretirement employee benefit credits capitalized to property, plant and equipment in 2018 ($27 million) partially offset by AFUDC on rate-regulated projects ($6 million).

~~Interest and related charges~~ increased 10%, primarily due to higher interest expense on long-term debt due to an issuance in the second quarter of 2018 and associated interest rates ($5 million), increased interest expense on commercial paper due to higher commercial paper rates ($2 million), a decrease in AFUDC ($2 million) and an increase in interest associated with tax deficiencies ($1 million), partially offset by an increase in deferred carrying costs ($5 million).

Income tax expense decreased ~~37%~~35%, primarily due to ~~the 2017 Tax Reform Act ($53 million) and~~ lower pre-tax ~~income ($18 million), partially offset by the absence of a settlement with state tax authorities ($5 million).~~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 30, 2018,~~March 31, 2019, Dominion Energy had ~~$2.9~~$3.5 billion of unused capacity under its credit facility. See Note 1516 to the Consolidated Financial Statements for more information.

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

	2018			2017			2019			2018
(millions)
Cash, restricted cash and equivalents at January 1	$	185		$	322		$	391		$	185
Cash flows provided by (used in):
Operating activities		3,711			3,672			1,171			1,232
Investing activities		(3,369	)		(4,868	)		(552	)		(1,183	)
Financing activities		(140	)		1,175			(383	)		100
Net increase (decrease) in cash, restricted cash and equivalents		202			(21	)
Cash, restricted cash and equivalents at September 30	$	387		$	301
Net increase in cash, restricted cash and equivalents								236			149
Cash, restricted cash and equivalents at March 31							$	627		$	334

Operating Cash Flows

Net cash provided by Dominion Energy’s operating activities ~~increased $39~~decreased $61 million, primarily due to an increase in property tax payments, decreased customer deposits, increased interest and net changes in other working capital items, partially offset by higher ~~merchant generation margin, favorable impact of weather and~~deferred fuel cost recoveries, the commencement of commercial operations of the Liquefaction ~~Project, partially offset by lower deferred fuel cost recoveries~~Facility and operations acquired in the ~~Virginia jurisdiction, increased interest expense and one-time rate credits to electric utility customers.~~SCANA Combination.

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.

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 Item 1A. Risk Factors in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017.~~2018.

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 30, 2018~~March 31, 2019 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⁾	$	21	$	—	$	21	$	98	$	—	$	98
Non-investment grade⁽²⁾		4		—		4		12		—		12
No external ratings:
Internally rated—investment grade⁽³⁾		4		—		4		18		1		17
Internally rated—non-investment grade⁽⁴⁾		32		—		32		56		—		56
Total	$	61	$	—	$	61	$	184	$	1	$	183

(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 ~~30%~~43% of the total net credit exposure.

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

(3)	The five largest counterparty exposures, combined, for this category represented approximately 6%10% of the total net credit exposure.

(4)	The five largest counterparty exposures, combined, for this category represented approximately ~~32%~~25% of the total net credit exposure.

Investing Cash Flows

Net cash used in Dominion Energy’s investing activities decreased ~~$1.5 billion,~~$631 million, primarily due to cash acquired in the SCANA Combination, proceeds from the sale of Blue Racer and a decrease in plant construction ~~including the Liquefaction Project,~~ and other property ~~additions and a decrease in acquisitions of solar development projects.~~additions.

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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018, 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.

Net cash used by Dominion Energy's financing activities was ~~$140~~$383 million for the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, compared to net cash provided by financing activities of ~~$1.2 billion~~$100 million for the ~~nine~~three months ended ~~September 30, 2017,~~March 31, 2018, primarily due to ~~lower net debt issuances,~~ lower issuance of common stock and higher common dividend payments.

In November 2017, Dominion Energy filed an 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 30, 2018~~March 31, 2019 was $7$19 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 ~~September 2018,~~January 2019, Dominion Energy ~~made a non-binding offer to~~acquired all outstanding partnership interests of Dominion Energy Midstream ~~to acquire all outstanding common units~~ not owned by Dominion ~~Energy. Under~~Energy through the ~~terms~~issuance of 22.5 million common shares. See Note 16 to the ~~offer, each outstanding publicly held~~Consolidated Financial Statements for additional information.

In January 2019, in connection with the SCANA Combination, Dominion Energy ~~Midstream common unit would be converted to 0.2468~~issued 95.6 million shares of Dominion Energy common shares. Also under the offer, the Series A Preferred Units not held by Dominion Energy would be converted into common units, pursuant to Dominion Energy Midstream’s partnership agreement, and receive the same per-unit consideration as the outstanding public common units.

~~The Board~~stock, valued at $6.8 billion, representing 0.6690 of ~~Directors~~a share of Dominion Energy ~~Midstream GP has authorized its conflicts committee~~common stock for each share of ~~independent directors to review and consider the offer. Any definitive agreement is subject to approval of a majority of the~~SCANA common stock outstanding ~~common units and a majority of the~~at closing. SCANA’s outstanding ~~common units and Series A Preferred Units voting together as a class, and is expected to contain customary closing conditions.~~

If a definitive agreement is reached and the proposed merger is consummated, Dominion Energy’s financial statements will reflect incremental income taxes currently attributable to the portion of Dominion Energy Midstream’s assets and liabilities attributable to the noncontrolling interest. In addition, Dominion Energy’s financial statements may reflect changes to the measurement of regulatory liability balances for income taxes refundable through future rates resulting from the 2017 Tax Reform Act that are currently attributable to the noncontrolling interest. Although Dominion Energy is currently unable to predict the magnitude and timing of these adjustments, such adjustments could have a material impact on Dominion Energy’s results of operations and financial condition.debt totaled $6.9 billion at closing.

See Note 1516 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018, 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 30, 2018,~~March 31, 2019, 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018, there is a discussion on the various covenants present in the enabling agreements underlying Dominion Energy’s debt. As of ~~September 30, 2018,~~March 31, 2019, there have been no material changes to debt covenants, nor any events of default under Dominion Energy’s debt covenants. The $6.0 billion joint revolving credit facility executed in March 2018, contains the same terms and covenants as the previous facilities with the exception of an increased maximum total debt to total capital ratio, with respect to Dominion Energy only, from 65% to 67.5%.

Future Cash Payments for Contractual Obligations and Planned Capital Expenditures

As of ~~September 30, 2018,~~March 31, 2019, 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018.

Use of Off-Balance Sheet Arrangements

As of ~~September 30, 2018,~~March 31, 2019, there have been no material changes in the off-balance sheet arrangements disclosed in MD&A in the Companies' Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, except for the forward sale agreements for 20 million shares of Dominion Energy common stock, as discussed in Note 15 of the Consolidated Financial Statements.2018.

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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018 and ~~Future Issues and Other Matters~~ Note 17 to the Consolidated Financial Statements in ~~MD&A in the Companies’ Quarterly Reports~~this report for additional information on ~~Form 10-Q for the quarters ended March 31, 2018 and June 30, 2018.~~various environmental matters.

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 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, Note 16 to the Consolidated Financial Statements in the Companies’ Quarterly Reports on Form 10-Q for the quarters ended March 31, 2018 and June 30, 2018 and Note 1617 in this report for additional information on various environmental matters.

~~Future Environmental Regulations~~

~~Air~~

In August 2015, the EPA issued final carbon standards for existing fossil fuel power plants. Known as the Clean Power Plan, the rule uses a set of measures for reducing emissions from existing sources that includes efficiency improvements at coal plants, displacing coal-fired generation with increased utilization of natural gas combined cycle units and expanding renewable resources. In August 2018, the EPA proposed the Affordable Clean Energy rule as a replacement for the Clean Power Plan. The Affordable Clean Energy rule applies to fossil fuel-fired steam electric generating units greater than or equal to 25 MW and does not apply to combustion turbines or units that burn biomass. The proposed 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 Affordable Clean Energy rule requires states to develop plans by 2022 to implement these performance standards which must be approved by the EPA. Given these developments and the associated federal and state regulatory and legal uncertainties, Dominion Energy cannot predict the potential financial statement impacts but believes the potential expenditures to comply could be material.

~~State Actions Related to Air and GHG Emissions~~

~~In August 2017, the Ozone Transport Commission released a draft model rule for control of NO~~_x ~~emissions from natural gas pipeline compressor fuel-fire prime movers. States within the ozone transport region, including states in which Dominion Energy has natural~~

gas operations, are expected to develop reasonably achievable control technology rules for existing sources based on the Ozone Transport Commission model rule. States outside of the Ozone Transport Commission may also consider the model rules in setting new reasonably achievable control technology standards. Several states in which Dominion Energy operates, including Pennsylvania, New York and Maryland, are developing state-specific regulations to control GHG emissions, including methane.

In January 2018, the VDEQ published for comments a proposed state carbon regulation program linked to the Regional Greenhouse Gas Initiative. The VDEQ has requested approval to re-propose the rule with a 15% lower initial carbon cap based on revised modeling that incorporates lower natural gas prices and additional solar capacity. The request was brought to the State Air Board for approval in October 2018 and a final rule is expected in mid-2019. Dominion Energy cannot currently estimate the potential financial statement impacts related to these matters, but there could be a material impact to its financial condition and/or cash flows.

Legal Matters

See Notes 3, 13 and 22 to the Consolidated Financial Statements ~~and~~ ~~Item 3. Legal Proceedings~~ in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018 and Notes 13 and 1617 to the Consolidated Financial Statements ~~and~~ ~~Item 1. Legal Proceedings~~ ~~in the Companies’ Quarterly Reports on Form 10-Q for the quarters ended March 31, 2018 and June 30, 2018 and Notes 13 and 16 to the Consolidated Financial Statements and~~ ~~Item 1. Legal~~ ~~Proceedings~~ in this report for additional information on various legal matters.

Regulatory Matters

See ~~Note~~Notes 3 and 13 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, Note 13 to the Consolidated Financial Statements in the Companies’ Quarterly Reports on Form 10-Q for the quarters ended March 31, 2018 and June 30, 2018 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. During the third ~~quarter~~and fourth quarters of 2018, a FERC stop work order together with delays in obtaining permits necessary for construction and delays in construction due to judicial actions impacted the cost and schedule for the project. As a result project cost estimates have increased from between $6.0 billion to $6.5 billion to between ~~$6.5~~$7.0 billion to ~~$7.0~~$7.5 billion, excluding financing costs. Atlantic Coast Pipeline ~~is pursuing a phased in-service approach with its customers, whereby it maintains~~expects to achieve a late ~~2019~~2020 in-service date for at least key segments of the project, while ~~pursuing a mid-2020 in-service date for~~ the ~~remaining segments~~remainder may extend into early 2021. Alternatively, if it takes longer to resolve the judicial issues, such as through appeal to the Supreme Court of the ~~project.~~U.S., full in-service could extend to the end of 2021 with total project cost estimated to increase an additional $250 million, resulting in total project cost estimates of $7.25 billion to $7.75 billion excluding financing costs. Abnormal weather, work delays (including due to judicial or regulatory action) and other conditions may result in further cost or schedule modifications in the future, which could result in a material impact to Dominion Energy’s cash flows, financial position and/or results of operations.

~~Nuclear Operating Licenses~~Millstone Agreement

~~Virginia Power has filed~~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 ~~application with~~“existing resource confirmed at risk” and subsequently participated in the ~~NRC~~state sponsored procurement for electricity. Being considered “at risk” allows the Department of Energy and Environmental Protection to ~~renew operating licenses~~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 between Dominion Energy, Eversource Energy and The United Illuminating Company for ~~its Surry power station~~Millstone to provide nine million MWh per year of electricity for ~~an additional 20~~ten years. ~~Under its current licenses, the two nuclear units are allowed~~This agreement is required to generate electricity through 2032 and 2033. A relicensing would extend their lives through 2052 and 2053. Virginia Power expects to submit a license extension application for the two units at its North Anna power station in 2020. Between the four units, Virginia Power estimates that it could spend approximately $4 billion over the next several years on the relicensing process. The existing regulatory framework in Virginia provides rate recovery mechanisms for such costs.

~~Significant Power Delivery Project~~

~~As part of the annual PJM regional transmission expansion plan process, PJM authorized additional electric transmission upgrade projects, including the Fork Union substation cut in,~~be approved by PURA, which is expected ~~to cost approximately $27 million and~~by the ~~Mt. Storm-Valley rebuild which is expected to cost approximately $285 million.~~end of 2019.

~~Significant Gas Infrastructure Projects~~

In December 2014, DETI entered into a precedent agreement with Atlantic Coast Pipeline for the Supply Header project, a project to provide approximately 1,500,000 Dths per day of firm transportation service to various customers. During the third quarter of 2018, a FERC stop work order impacted the cost of the project. As a result, project cost estimates have increased from between $550 million

~~to $600 million to between $600 million to $650 million, excluding financing costs. DETI anticipates maintaining a late 2019 in-service date.~~

In June 2015, Cove Point executed two binding precedent agreements for the approximately $150 million Eastern Market Access Project. In January 2018, Cove Point received FERC authorization to construct and operate the project facilities, which are expected to be placed in service in late 2019. In October 2018, Cove Point announced it is evaluating alternatives to a proposed Charles County, Maryland compressor station that was initially part of this project. Cove Point is working with the project customers to evaluate alternatives to meet their needs. Any resulting modification from ongoing negotiation with the project customers could impact Dominion Energy’s financial results of operations and/or financial position.

~~Other Matters~~

While management has no plans which may affect the carrying value of Millstone, based on potential future economic and other factors, including, but not limited to, market power prices, results of capacity auctions, legislative and regulatory solutions to ensure nuclear plants are fairly compensated for their carbon-free generation, and the impact of potential EPA carbon rules, there is a risk that Millstone may be evaluated for an early retirement date. Should management make any decision on a potential early retirement date, the precise date and the resulting financial statement impacts, which could be material to Dominion Energy, may be affected by a number of factors, including any potential regulatory or legislative solutions, results of any transmission system reliability study assessments, and decommissioning requirements, among other factors.

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 Dominion Energy Gas holds commodity-based financial derivative instruments held for non-trading purposes associated with sales of NGLs.

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 $4$23 million and $5$6 million of Dominion Energy’s commodity-based derivative instruments as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, 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 ~~the~~ fair value of ~~$44~~$45 million and $51 million of Virginia Power’s commodity-based derivative instruments as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

A hypothetical 10% increase in commodity prices would have resulted in a decrease in fair value of $3$2 million and $4$1 million of Dominion Energy Gas’ commodity-based derivative instruments as of ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

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

Interest Rate Risk

The Companies manage their interest rate risk exposure predominantly by maintaining a balance of fixed and variable rate debt. They also enter into interest rate sensitive derivatives, including interest rate swaps and interest rate lock agreements. For variable rate debt ~~and interest rate swaps designated under fair value hedging and~~ outstanding for Dominion Energy, a hypothetical 10% increase in market interest rates would result in a ~~$26~~$28 million and ~~$12~~$24 million decrease in earnings at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~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 30, 2018~~March 31, 2019 or December 31, ~~2017.~~2018.

The Companies also use interest rate derivatives, including forward-starting swaps, as cash flow hedges of forecasted interest payments. As of ~~September 30,~~March 31, 2019, Dominion Energy, Virginia Power and Dominion Energy Gas had $6.8 billion, $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 $172 million, $101 million and $21 million, respectively, in the fair value of Dominion Energy, Virginia Power and Dominion Energy Gas’ interest rate derivatives at March 31, 2019. As of December 31, 2018, Dominion Energy, Virginia Power and Dominion Energy Gas had ~~$4.4~~$5.9 billion, ~~$1.6~~$1.9 billion and $1.1 billion, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of ~~$79~~$147 million, ~~$50~~$94 million and ~~$12~~$17 million, respectively, in the fair value of Dominion Energy, Virginia Power and Dominion Energy Gas’ interest rate derivatives at ~~September 30, 2018. As of~~ December 31, 2017, Dominion Energy and Virginia Power had $3.5 billion and $1.5 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 $86 million and $67 million, respectively, in the fair value of Dominion Energy and Virginia Power’s interest rate derivatives at December 31, 2017. Dominion Energy Gas had no interest rate derivatives outstanding at December 31, 2017.2018.

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 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, Dominion Energy and Dominion Energy Gas had $280 million (€250 million) in aggregate notional amounts of these foreign currency swaps outstanding. A hypothetical 10% decrease in market interest rates would have resulted in a decrease of $9$4 million and $6$8 million, in the fair value of Dominion Energy Gas' foreign currency swaps at ~~September 30, 2018~~March 31, 2019 and December 31, ~~2017,~~2018, respectively.

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 ~~$350~~$448 million for the ~~nine~~three months ended ~~September 30, 2018.~~March 31, 2019. Dominion Energy recognized net ~~realized gains~~investment losses (including investment income) on nuclear decommissioning trust and rabbi trust investments of ~~$137~~$36 million for the ~~nine~~three months ended ~~September 30, 2017~~March 31, 2018 and ~~$167~~$135 million for the year ended December 31, ~~2017.~~2018. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Dominion Energy recorded in AOCI and regulatory liabilities, a net increase in unrealized gains on debt investments of $39 million for the three months ended March 31, 2019 and recorded a net decrease in unrealized gains on debt investments of ~~$36 million and an additional unrealized loss of $10~~$28 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2018 and ~~recorded a net increase in unrealized gains on debt and equity investments of $271 million for the nine months ended September 30, 2017 and $462~~$36 million for the year ended December 31, ~~2017.~~2018.

Virginia Power recognized net investment gains on nuclear decommissioning trust investments of ~~$163~~$202 million for the ~~nine~~three months ended ~~September 30, 2018.~~March 31, 2019. Virginia Power recognized net ~~realized gains~~investment losses (including investment income) on nuclear decommissioning trust investments of ~~$59~~$20 million for the ~~nine~~three months ended ~~September 30, 2017~~March 31, 2018 and ~~$76~~$44 million for the year ended December 31, ~~2017.~~2018. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Virginia Power recorded in AOCI and regulatory liabilities, a net increase in unrealized gains on debt investments of $20 million for the three months ended March 31, 2019 and recorded a net decrease in unrealized gains on debt investments of ~~$19 million with an additional unrealized loss of $5~~$14 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2018 and ~~recorded a net increase in unrealized gains on debt and equity investments of $127 million for the nine months ended September 30, 2017 and $216~~$21 million for the year ended December 31, ~~2017.~~2018.

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~~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’s,~~Energy, Virginia ~~Power’s,~~Power and Dominion Energy Gas’ CEO and CFO have concluded that each of their respective ~~Company’s~~company’s disclosure controls and procedures are effective.

In August 2018, Dominion Energy, Virginia Power, and Dominion Energy Gas transitioned to a new fixed assets tracking system. Throughout this system implementation, Dominion Energy, Virginia Power, and Dominion Energy Gas appropriately considered internal controls over financial reporting.

~~Other than with respect to this item, there~~There were no changes that occurred during the last fiscal quarter that materially affected, or are reasonably likely to materially affect Dominion ~~Energy’s,~~Energy, Virginia ~~Power’s,~~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. In addition, Virginia Power has been working cooperatively with both the VDEQ and the EPA to resolve certain other alleged violations collectively. Virginia Power anticipates that a negotiated resolution of this matter could result in a penalty in excess of $100,000.

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

Notes 3, 13 and 22 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, ~~2017, as updated in Current Report on Form 8-K, filed June 6,~~ 2018.

~~Notes 13 and 16 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2018.~~

~~Notes 13 and 16 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended June 30, 2018.~~

Notes 13 and 1617 to the Consolidated Financial Statements in this report.

ITEM 1A. RISK FACTORS

The Companies’ businesses are influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond the Companies’ control. A number of these risk factors have been identified in the Companies’ Annual Report on Form 10-K for the year ended December 31, ~~2017,~~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, ~~2017.~~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⁾
7/1/18-7/31/18

11,968

$
68.21

—

19,629,059 shares/
$1.18 billion
8/1/18-8/31/18

—

—

—

19,629,059 shares/
$1.18 billion
9/1/18-9/30/18

5,698

71.84

—

19,629,059 shares/
$1.18 billion
Total

17,666

$
69.38

—

19,629,059 shares/
$1.18 billion

Period	Total Number of Shares (or Units) Purchased⁽¹⁾		Average Price Paid per Share (or Unit)⁽²⁾		Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs		Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased under the Plans or Programs⁽³⁾
1/1/19-1/31/19		28,001	$	70.57		—	19,629,059 shares/ $1.18 billion
2/1/19-2/28/19		64,923		70.97		—	19,629,059 shares/ $1.18 billion
3/1/19-3/31/19		669		74.79		—	19,629,059 shares/ $1.18 billion
Total		93,593	$	70.88		—	19,629,059 shares/ $1.18 billion

(1)	In ~~July~~January, February and ~~September 2018, 11,968~~March 2019, 28,001 shares, 64,923 shares and ~~5,698~~669 shares, respectively, 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


3.1.a	Dominion Energy, Inc. Articles of Incorporation as amended and restated, effective May 10, 2017 (Exhibit 3.1, Form 8-K filed May 10, 2017, 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. Amended and Restated Bylaws, effective May 10, 2017 (Exhibit 3.2, Form 8-K filed May 10, 2017, 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 ~~September~~May 12, ~~2013~~2017 (Exhibit 3.2, Form 8-K filed May 16, 2017, 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 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

4.2	Indenture, dated as of June 1, 2015, between Dominion Resources, Inc. and Deutsche Bank Trust Company Americas, as Trustee (Exhibit 4.1, Form 8-K filed June 15, 2015, File No. 1-8489); First Supplemental Indenture, dated as of June 1, 2015 (Exhibit 4.2, Form 8-K filed June 15, 2015, File No. 1-8489); Second Supplemental Indenture, dated as of September 1, 2015 (Exhibit 4.2, Form 8-K filed September 24, 2015, File No. 1-8489); Third Supplemental Indenture, dated as of February 1, 2016 (Exhibit 4.7, Form 10-K for the fiscal year ended December 31, 2015 filed February 26, 2016, File No. 1-8489); Fourth Supplemental Indenture, dated as of August 1, 2016 (Exhibit 4.2, Form 8-K filed August 9, 2016, File No. 1-8489); Fifth Supplemental Indenture, dated as of August 1, 2016 (Exhibit 4.3, Form 8-K filed August 9, 2016, File No. 1-8489); Sixth Supplemental Indenture, dated as of August 1, 2016 (Exhibit 4.4, Form 8-K filed August 9, 2016, File No. 1-8489); Seventh Supplemental Indenture, dated as of September 1, 2016 (Exhibit 4.1, Form 10-Q filed November 9, 2016, File No. 1-8489); Eighth Supplemental Indenture, dated as of December 1, 2016 (Exhibit 4.7, Form 10-K for the fiscal year ended December 31, 2016 filed February 28, 2017, File No. 1-8489); Ninth Supplemental Indenture, dated as of January 1, 2017 (Exhibit 4.2, Form 8-K filed January 12, 2017, File No. 1-8489); Tenth Supplemental Indenture, dated as of January 1, 2017 (Exhibit 4.3, Form 8-K filed January 12, 2017, File No. 1-8489); Eleventh Supplemental Indenture, dated as of March 1, 2017 (Exhibit 4.3, Form 10-Q filed May 4, 2017, File No. 1-8489); Twelfth Supplemental Indenture, dated as of June 1, 2017 (Exhibit 4.2, Form 10-Q filed August 3, 2017, File No. 1-8489); Thirteenth Supplemental Indenture, dated December 1, 2017 (Exhibit 4.8, Form 10-K for the fiscal year ended December 31, 2017 filed February 27, 2018, File No. 1-8489); Fourteenth Supplemental Indenture, dated May 1, 2018 (Exhibit 4.2, Form 10-Q filed August 2, 2018, File No. 1-8489); Fifteenth Supplemental Indenture, dated June 1, 2018 (Exhibit 4.2, Form 8-K, filed June 5, 2018, File No. 1-8489); Sixteenth Supplemental Indenture, dated March 1, 2019 (Exhibit 4.2, Form 8-K, filed March 13, 2019, File No. 1-8489).	X

Exhibit Number	Description	Dominion Energy	Virginia Power	Dominion Energy Gas
~~4.1~~10.1	$6,000,000,000 Third Amended and Restated Revolving Credit Agreement, dated March 22, 2019, among Dominion Energy, Inc., Virginia Electric and Power Company, ~~and~~ Dominion Energy Gas Holdings, LLC, ~~agree to furnish to the Securities~~Questar Gas Company, South Carolina Electric & Gas Company, JPMorgan Chase Bank, N.A., as Administrative Agent, Mizuho Bank, Ltd., Bank of America, N.A., The Bank of Nova Scotia and ~~Exchange Commission upon request any~~Wells Fargo Bank, N.A., as Syndication Agents, and 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.~~lenders named therein (Exhibit 10.1, Form 8-K filed March 26, 2019, File No. 1-8489).	X	X	X

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

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 30, 2018,~~March 31, 2019, filed on ~~November 2, 2018,~~May 3, 2019, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income (iii) Consolidated Balance Sheets, (iv) Consolidated Statements of Equity, (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements. The following financial statements from Virginia Electric and Power Company’s Quarterly Report on Form 10-Q for the quarter ended ~~September 30, 2018,~~March 31, 2019, filed on ~~November 2, 2018,~~May 3, 2019, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income, (iii) Consolidated Balance Sheets, (iv) Consolidated ~~Statement~~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 30, 2018,~~March 31, 2019, filed on ~~November 2, 2018,~~May 3, 2019, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income, (iii) Consolidated Balance Sheets, (iv) Consolidated ~~Statement~~Statements of Equity, (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements.	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 2, 2018~~May 3, 2019	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

	VIRGINIA ELECTRIC AND POWER COMPANY Registrant

~~November 2, 2018~~May 3, 2019	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

	DOMINION ENERGY GAS HOLDINGS, LLC Registrant

~~November 2, 2018~~May 3, 2019	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

~~119~~112

	Operating Revenue			Electric Fuel and Other Energy-Related Purchases			Total
(millions)
Three Months Ended September 30, 2018
Total gains (losses) included in earnings	$	—		$	(7	)	$	(7	)
Three Months Ended September 30, 2017
Total gains (losses) included in earnings	$	1		$	(12	)	$	(11	)
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		1			—			1
Nine Months Ended September 30, 2018
Total gains (losses) included in earnings	$	(2	)	$	(25	)	$	(27	)
Nine Months Ended September 30, 2017
Total gains (losses) included in earnings	$	1		$	(37	)	$	(36	)
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		1			—			1

	September 30, 2018						December 31, 2017
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	32	$	—	$	32	$	76	$	—	$	76
Exchange		68		—		68		120		—		120
Interest rate contracts:
Over-the-counter		42		—		42		85		—		85
Foreign currency contracts:
Over-the-counter		3		—		3		2		—		2
Total derivatives, subject to a master netting or similar arrangement		145		—		145		283		—		283
Total derivatives, not subject to a master netting or similar arrangement		—		—		—		1		—		1
Total	$	145	$	—	$	145	$	284	$	—	$	284

	September 30, 2018
(millions)
Assets:
Current assets	$	37
Property, plant and equipment, net		940
Other assets		52
Total assets	$	1,029

Liabilities:
Current liabilities	$	8
Asset retirement obligation		1
Total liabilities	$	9