Edgar Filing: DOMINION ENERGY INC /VA/

d-10q_20180630.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended June 30, 2018

☐	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 ☒

At July 13, 2018, the latest practicable date for determination, Dominion Energy, Inc. had 653,765,671 shares of common stock outstanding and Virginia Electric and Power Company had 274,723 shares of common stock outstanding. Dominion Energy, Inc. is the sole holder of Virginia Electric and Power Company’s common stock. Dominion Energy, Inc. holds all of the membership interests of Dominion Energy Gas Holdings, LLC.

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

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

COMBINED INDEX

		Page Number
	Glossary of Terms	3

	PART I. Financial Information

Item 1.	Financial Statements	7
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	94
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	110
Item 4.	Controls and Procedures	111

	PART II. Other Information

Item 1.	Legal Proceedings	112
Item 1A.	Risk Factors	112
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	113
Item 5.	Other Information	113
Item 6.	Exhibits	115

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
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
bcf		Billion cubic feet
Bear Garden		A 590 MW combined-cycle, natural gas-fired power station in Buckingham County, Virginia
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
CAA		Clean Air Act
CAISO		California Independent System Operator
CCR		Coal combustion residual
CEO		Chief Executive Officer
CERCLA		Comprehensive Environmental Response, Compensation and Liability Act of 1980, also known as Superfund
CFO		Chief Financial Officer
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, calculated as the difference between 65 degrees and the average temperature for that day
Cove Point		Dominion Energy Cove Point LNG, LP
CPCN		Certificate of Public Convenience and Necessity
CWA		Clean Water Act
DECG		Dominion Energy Carolina Gas Transmission, LLC
DES		Dominion Energy Services, Inc.
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
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
FASB		Financial Accounting Standards Board
FERC		Federal Energy Regulatory Commission
Four Brothers		Four Brothers Solar, LLC, a limited liability company owned by Dominion Energy and Four Brothers Holdings, LLC, a wholly-owned subsidiary of NRG
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
Granite Mountain		Granite Mountain Holdings, LLC, a limited liability company owned by Dominion Energy and Granite Mountain Renewables, LLC, a wholly-owned subsidiary of NRG
Greensville County		An approximately 1,588 MW natural gas-fired combined-cycle power station under construction in Greensville County, Virginia
Heating degree days		Units measuring the extent to which the average daily temperature is less than 65 degrees Fahrenheit, calculated as the difference between 65 degrees and the average temperature for that day
Hope		Hope Gas, Inc., doing business as Dominion Energy West Virginia
Iron Springs		Iron Springs Holdings, LLC, a limited liability company owned by Dominion Energy and Iron Springs Renewables, LLC, a wholly-owned subsidiary of NRG
Iroquois		Iroquois Gas Transmission System, L.P.
ISO-NE		ISO New England, Inc.
Kewaunee		Kewaunee nuclear power station
kV		Kilovolt
Liquefaction Project		A natural gas export/liquefaction facility at Cove Point

Abbreviation or Acronym		Definition
LNG		Liquefied natural gas
MATS		Utility Mercury and Air Toxics Standard Rule
MD&A		Management’s Discussion and Analysis of Financial Condition and Results of Operations
MGD		Million gallons a day
Millstone		Millstone nuclear power station
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
NO_x		Nitrogen oxide
NRC		Nuclear Regulatory Commission
NRG		The legal entity, NRG Energy, Inc., one or more of its consolidated subsidiaries or operating segments, or the entirety of NRG Energy, Inc. and its consolidated subsidiaries
NSPS		New Source Performance Standards
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
PREP		Pipeline Replacement and Expansion Program, a program of replacing, upgrading and expanding natural gas utility infrastructure deployed by Hope
PSD		Prevention of Significant Deterioration
Questar Gas		Questar Gas Company
Rider B		A rate adjustment clause associated with the recovery of costs related to the conversion of three of Virginia Power’s coal-fired power stations to biomass
Rider BW		A rate adjustment clause associated with the recovery of costs related to Brunswick County
Rider GV		A rate adjustment clause associated with the recovery of costs related to Greensville County
Rider R		A rate adjustment clause associated with the recovery of costs related to Bear Garden
Rider S		A rate adjustment clause associated with the recovery of costs related to the Virginia City Hybrid Energy Center
Rider T1		A rate adjustment clause to recover the difference between revenues produced from transmission rates included in base rates, and the new total revenue requirement developed annually for the rate years effective September 1
Rider US-2		A rate adjustment clause associated with the recovery of costs related to Woodland, Scott Solar and Whitehouse

Abbreviation or Acronym		Definition
Rider US-3		A rate adjustment clause associated with the recovery of costs related to Colonial Trail West and Spring Grove 1
Rider W		A rate adjustment clause associated with the recovery of costs related to Warren County
Riders C1A and C2A		Rate adjustment clauses associated with the recovery of costs related to certain DSM programs approved in DSM cases
ROE		Return on equity
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 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		South Carolina Electric & Gas Company, a wholly-owned subsidiary of SCANA
Scott Solar		A 17 MW utility-scale solar power station in Powhatan County, Virginia
SEC		Securities and Exchange Commission
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, Inc.
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 City Hybrid Energy Center		A 610 MW baseload carbon-capture compatible, clean coal powered electric generation facility in Wise County, Virginia
Virginia Commission		Virginia State Corporation Commission
Virginia Power		The legal entity, Virginia Electric and Power Company, one or more of its consolidated subsidiaries or operating segments, or the entirety of Virginia Electric and Power Company and its consolidated subsidiaries
VOC		Volatile organic compounds
Warren County		A 1,350 MW combined-cycle, natural gas-fired power station in Warren County, Virginia
Whitehouse		A 20 MW utility-scale solar power station in Louisa County, Virginia
Woodland		A 19 MW utility-scale solar power station in Isle of Wight County, Virginia
Wyoming Commission		Wyoming Public Service Commission

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,					Six Months Ended June 30,
	2018		2017			2018		2017
(millions, except per share amounts)
Operating Revenue⁽¹⁾	$	3,088	$	2,813		$	6,554	$	6,197
Operating Expenses
Electric fuel and other energy-related purchases		623		498			1,367		1,073
Purchased (excess) electric capacity		23		(12	)		37		(29	)
Purchased gas		64		112			404		417
Other operations and maintenance		1,007		827			1,803		1,611
Depreciation, depletion and amortization		463		467			961		936
Other taxes		166		168			365		357
Total operating expenses		2,346		2,060			4,937		4,365
Income from operations		742		753			1,617		1,832
Other income		185		108			285		270
Interest and related charges		361		308			675		600
Income from operations including noncontrolling interests before income tax expense		566		553			1,227		1,502
Income tax expense		88		136			223		411
Net Income Including Noncontrolling Interests		478		417			1,004		1,091
Noncontrolling Interests		29		27			52		69
Net Income Attributable to Dominion Energy	$	449	$	390		$	952	$	1,022
Earnings Per Common Share
Net income attributable to Dominion Energy - Basic	$	0.69	$	0.62		$	1.46	$	1.63
Net income attributable to Dominion Energy - Diluted		0.69		0.62			1.46		1.63
Dividends Declared Per Common Share	$	0.8350	$	0.7550		$	1.670	$	1.510

(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 June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
(millions)
Net income including noncontrolling interests	$	478		$	417		$	1,004		$	1,091
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		(33	)		28			78			71
Changes in unrealized net gains (losses) on investment securities⁽²⁾		(5	)		35			(18	)		93
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities⁽³⁾		33			(18	)		41			(41	)
Net realized (gains) losses on investment securities⁽⁴⁾		—			(4	)		1			(32	)
Net pension and other postretirement benefit costs⁽⁵⁾		17			11			42			24
Changes in other comprehensive income from equity method investees⁽⁶⁾		1			1			1			2
Total other comprehensive income		13			53			145			117
Comprehensive income including noncontrolling interests		491			470			1,149			1,208
Comprehensive income attributable to noncontrolling interests		29			27			53			69
Comprehensive income attributable to Dominion Energy	$	462		$	443		$	1,096		$	1,139

(1)	Net of $11 million and $(17) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(26) million and $(44) million tax for the six months ended June 30, 2018 and 2017, respectively.

(2)	Net of $2 million and $(18) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $6 million and $(53) million tax for the six months ended June 30, 2018 and 2017, respectively.

(3)	Net of $(11) million and $11 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(14) million and $25 million tax for the six months ended June 30, 2018 and 2017, respectively.

(4)	Net of $(1) million and $2 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million and $18 million tax for the six months ended June 30, 2018 and 2017, respectively.

(5)	Net of $(7) million and $(10) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(8) million and $(18) million tax for the six months ended June 30, 2018 and 2017, respectively.

(6)	Net of $(1) million and $— million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million tax for both the six months ended June 30, 2018 and 2017.

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

DOMINION ENERGY, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2018			December 31, 2017⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	190		$	120
Customer receivables (less allowance for doubtful accounts of $19 and $17)		1,510			1,660
Other receivables (less allowance for doubtful accounts of $3 and $2)⁽²⁾		133			126
Inventories		1,429			1,477
Regulatory assets		616			294
Other		732			657
Total current assets		4,610			4,334
Investments
Nuclear decommissioning trust funds		5,159			5,093
Investment in equity method affiliates		1,710			1,544
Other		339			327
Total investments		7,208			6,964
Property, Plant and Equipment
Property, plant and equipment		76,458			74,823
Accumulated depreciation, depletion and amortization		(21,854	)		(21,065	)
Total property, plant and equipment, net		54,604			53,758
Deferred Charges and Other Assets
Goodwill		6,405			6,405
Regulatory assets		2,395			2,480
Other		2,853			2,644
Total deferred charges and other assets		11,653			11,529
Total assets	$	78,075		$	76,585

(1)	Dominion Energy’s Consolidated Balance Sheet at December 31, 2017 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)

	June 30, 2018			December 31, 2017⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	2,950		$	3,078
Short-term debt		2,745			3,298
Accounts payable		660			875
Other⁽²⁾		2,563			2,385
Total current liabilities		8,918			9,636
Long-Term Debt
Long-term debt		26,679			25,588
Junior subordinated notes		3,981			3,981
Remarketable subordinated notes		1,382			1,379
Credit facility borrowings		73			—
Total long-term debt		32,115			30,948
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		4,844			4,523
Regulatory liabilities		7,065			6,916
Other⁽²⁾		5,097			5,192
Total deferred credits and other liabilities		17,006			16,631
Total liabilities		58,039			57,215
Commitments and Contingencies (see Note 16)
Equity
Common stock – no par⁽³⁾		10,782			9,865
Retained earnings		8,820			7,936
Accumulated other comprehensive loss		(1,538	)		(659	)
Total common shareholders' equity		18,064			17,142
Noncontrolling interests		1,972			2,228
Total equity		20,036			19,370
Total liabilities and equity	$	78,075		$	76,585

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

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

(3)	1 billion shares authorized; 654 million shares and 645 million shares outstanding at June 30, 2018 and December 31, 2017, 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
	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							1,022						1,022			69			1,091
Contributions from NRG to Four Brothers and Three Cedars													—			9			9
Issuance of common stock		2		156									156						156
Stock awards (net of change in unearned compensation)				11									11						11
Dividends and distributions							(949	)					(949	)		(82	)		(1,031	)
Other comprehensive income, net of tax										117			117						117
Other							11						11			1			12
June 30, 2017		630	$	8,717		$	6,938		$	(682	)	$	14,973		$	2,232		$	17,205

December 31, 2017		645	$	9,865		$	7,936		$	(659	)	$	17,142		$	2,228		$	19,370
Cumulative-effect of changes in accounting principles				(127	)		1,029			(1,023	)		(121	)		127			6
Net income including noncontrolling interests							952						952			52			1,004
Issuance of common stock		9		662									662						662
Sale of Dominion Energy Midstream common units - net of offering costs													—			4			4
Remeasurement of noncontrolling interest in Dominion Energy Midstream				375									375			(375	)		—
Stock awards (net of change in unearned compensation)				12									12						12
Dividends and distributions							(1,089	)					(1,089	)		(65	)		(1,154	)
Other comprehensive income, net of tax										144			144			1			145
Other				(5	)		(8	)					(13	)					(13	)
June 30, 2018		654	$	10,782		$	8,820		$	(1,538	)	$	18,064		$	1,972		$	20,036

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

DOMINION ENERGY, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2018			2017
(millions)
Operating Activities
Net income including noncontrolling interests	$	1,004		$	1,091
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)		1,106			1,088
Deferred income taxes and investment tax credits		229			406
Proceeds from assignment of tower rental portfolio		—			91
Contribution to pension plan		—			(75	)
Gains on sales of assets		(44	)		—
Provision for rate credits to electric utility customers		215			—
Charge associated with future ash pond and landfill closure costs		81			—
Charge associated with FERC-regulated plant disallowance		129			—
Other adjustments		(42	)		(64	)
Changes in:
Accounts receivable		158			307
Inventories		31			21
Deferred fuel and purchased gas costs, net		(295	)		(79	)
Prepayments		(15	)		32
Accounts payable		(151	)		(211	)
Accrued interest, payroll and taxes		(90	)		(73	)
Customer deposits		108			12
Margin deposit assets and liabilities		(34	)		54
Net realized and unrealized changes related to derivative activities		82			34
Other operating assets and liabilities		(47	)		(274	)
Net cash provided by operating activities		2,425			2,360
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(2,046	)		(2,748	)
Acquisition of solar development projects		(51	)		(280	)
Proceeds from sales of securities		844			1,119
Purchases of securities		(890	)		(1,156	)
Proceeds from assignments of shale development rights		44			—
Contributions to equity method affiliates		(134	)		(252	)
Other		(3	)		(4	)
Net cash used in investing activities		(2,236	)		(3,321	)
Financing Activities
Issuance of short-term notes		1,450			—
Repayment of short-term debt, net		(553	)		(322	)
Issuance of long-term debt		2,400			2,730
Repayment of long-term debt		(2,840	)		(490	)
Credit facility borrowings		73			—
Issuance of common stock		662			156
Common dividend payments		(1,089	)		(949	)
Other		(123	)		(162	)
Net cash provided by (used in) financing activities		(20	)		963
Increase in cash, restricted cash and equivalents		169			2
Cash, restricted cash and equivalents at beginning of period		185			322
Cash, restricted cash and equivalents at end of period	$	354		$	324
Supplemental Cash Flow Information
Significant noncash investing and financing activities:⁽¹⁾⁽²⁾
Accrued capital expenditures	$	253		$	270

(1)	See Note 10 for noncash activities related to equity method investments.

(2)	See Note 15 for noncash activities related to the remeasurement of Dominion Energy’s noncontrolling 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 June 30,					Six Months Ended June 30,
	2018		2017			2018		2017
(millions)
Operating Revenue⁽¹⁾	$	1,829	$	1,747		$	3,577	$	3,578
Operating Expenses
Electric fuel and other energy-related purchases⁽¹⁾		508		409			1,099		865
Purchased (excess) electric capacity		23		(12	)		37		(29	)
Other operations and maintenance:
Affiliated suppliers		74		75			157		153
Other		365		304			681		600
Depreciation and amortization		247		280			544		566
Other taxes		79		78			162		157
Total operating expenses		1,296		1,134			2,680		2,312
Income from operations		533		613			897		1,266
Other income		21		13			24		44
Interest and related charges⁽¹⁾		126		125			258		245
Income before income tax expense		428		501			663		1,065
Income tax expense		89		183			140		391
Net Income	$	339	$	318		$	523	$	674

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

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
(millions)
Net income	$	339		$	318		$	523		$	674
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		2			(3	)		7			(3	)
Changes in unrealized net gains (losses) on nuclear decommissioning trust funds⁽²⁾		(2	)		4			(2	)		11
Amounts reclassified to net income:
Net derivative (gains) losses on derivative-hedging activities⁽³⁾		—			1			—			1
Net realized (gains) losses on nuclear decommissioning trust funds⁽⁴⁾		—			(1	)		—			(4	)
Total other comprehensive income		—			1			5			5
Comprehensive income	$	339		$	319		$	528		$	679

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

(2)	Net of $— million and $(3) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $1 million and $(7) million tax for the six months ended June 30, 2018 and 2017, respectively.

(3)	Net of $— million tax for both the three and six months ended June 30, 2018 and 2017.

(4)	Net of $— million tax for both the three months ended June 30, 2018 and 2017, and net of $— million and $2 million tax for the six months ended June 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)

	June 30, 2018			December 31, 2017⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	20		$	14
Customer receivables (less allowance for doubtful accounts of $10 at both dates)		994			951
Other receivables (less allowance for doubtful accounts of $1 at both dates)		46			64
Affiliated receivables		73			3
Inventories (average cost method)		814			850
Regulatory assets		552			205
Other⁽²⁾		169			137
Total current assets		2,668			2,224
Investments
Nuclear decommissioning trust funds		2,449			2,399
Other		4			3
Total investments		2,453			2,402
Property, Plant and Equipment
Property, plant and equipment		43,444			42,329
Accumulated depreciation and amortization		(13,683	)		(13,277	)
Total property, plant and equipment, net		29,761			29,052
Deferred Charges and Other Assets
Regulatory assets		729			810
Other⁽²⁾		719			651
Total deferred charges and other assets		1,448			1,461
Total assets	$	36,330		$	35,139

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

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

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30, 2018			December 31, 2017⁽¹⁾
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	—		$	850
Short-term debt		1,158			542
Accounts payable		296			361
Payables to affiliates		109			125
Affiliated current borrowings		25			33
Other⁽²⁾		1,321			1,009
Total current liabilities		2,909			2,920
Long-Term Debt		11,091			10,496
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,894			2,728
Asset retirement obligations		1,302			1,149
Regulatory liabilities		4,877			4,760
Other⁽²⁾		760			862
Total deferred credits and other liabilities		9,833			9,499
Total liabilities		23,833			22,915
Commitments and Contingencies (see Note 16)
Common Shareholder’s Equity
Common stock – no par⁽³⁾		5,738			5,738
Other paid-in capital		1,113			1,113
Retained earnings		5,655			5,311
Accumulated other comprehensive income (loss)		(9	)		62
Total common shareholder’s equity		12,497			12,224
Total liabilities and shareholder’s equity	$	36,330		$	35,139

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

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

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

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENT OF COMMON SHAREHOLDER’S EQUITY

(Unaudited)

	Common Stock
	Shares		Amount		Other Paid-In Capital		Retained Earnings			AOCI			Total
(millions, except for shares)	(thousands)
December 31, 2017		275	$	5,738	$	1,113	$	5,311		$	62		$	12,224
Cumulative-effect of changes in accounting principles								79			(76	)		3
Net income								523						523
Dividends								(257	)					(257	)
Other comprehensive income, net of tax											5			5
Other								(1	)					(1	)
June 30, 2018		275	$	5,738	$	1,113	$	5,655		$	(9	)	$	12,497

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

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2018			2017
(millions)
Operating Activities
Net income	$	523		$	674
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		632			665
Deferred income taxes and investment tax credits		137			167
Proceeds from assignment of tower rental portfolio		—			91
Charge associated with future ash pond and landfill closure costs		81			—
Provision for rate credits to customers		215			—
Other adjustments		(19	)		(20	)
Changes in:
Accounts receivable		(26	)		92
Affiliated receivables and payables		(86	)		39
Inventories		36			19
Prepayments		(6	)		(4	)
Deferred fuel expenses, net		(357	)		(78	)
Accounts payable		(45	)		(32	)
Accrued interest, payroll and taxes		13			23
Net realized and unrealized changes related to derivative activities		54			27
Asset retirement obligations		(18	)		(42	)
Other operating assets and liabilities		64			(130	)
Net cash provided by operating activities		1,198			1,491
Investing Activities
Plant construction and other property additions		(1,170	)		(1,216	)
Purchases of nuclear fuel		(55	)		(116	)
Acquisition of solar development projects		(43	)		(3	)
Proceeds from sales of securities		414			498
Purchases of securities		(436	)		(517	)
Other		4			(17	)
Net cash used in investing activities		(1,286	)		(1,371	)
Financing Activities
Issuance of short-term debt, net		616			351
Repayment of affiliated current borrowings, net		(8	)		(250	)
Issuance of long-term debt		700			750
Repayment of long-term debt		(951	)		(78	)
Common dividend payments to parent		(257	)		(854	)
Other		(6	)		(6	)
Net cash provided by (used in) financing activities		94			(87	)
Increase in cash, restricted cash and equivalents		6			33
Cash, restricted cash and equivalents at beginning of period		24			11
Cash, restricted cash and equivalents at end of period	$	30		$	44
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	159		$	169

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
(millions)
Operating Revenue⁽¹⁾	$	459	$	422	$	985	$	912
Operating Expenses
Purchased gas⁽¹⁾		—		38		29		81
Other energy-related purchases		31		2		62		7
Other operations and maintenance:
Affiliated suppliers		26		20		49		45
Other		295		148		418		301
Depreciation and amortization		53		56		112		110
Other taxes		47		43		107		97
Total operating expenses		452		307		777		641
Income from operations		7		115		208		271
Earnings from equity method investee		5		4		14		11
Other income		32		27		65		52
Interest and related charges⁽¹⁾		26		24		51		47
Income from operations before income taxes		18		122		236		287
Income tax expense		3		45		55		102
Net Income	$	15	$	77	$	181	$	185

(1)	See Note 18 for amounts attributable to related parties.

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
(millions)
Net income	$	15		$	77		$	181		$	185
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities⁽¹⁾		(20	)		11			(7	)		2
Amounts reclassified to net income:
Net derivative (gains) losses -hedging activities⁽²⁾		14			(12	)		11			(1	)
Net pension and other postretirement benefit costs⁽³⁾		1			2			2			2
Total other comprehensive income (loss)		(5	)		1			6			3
Comprehensive income	$	10		$	78		$	187		$	188

(1)	Net of $7 million and $(7) million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $3 million and $(1) million tax for the six months ended June 30, 2018 and 2017, respectively.

(2)	Net of $(5) million and $7 million tax for the three months ended June 30, 2018 and 2017, respectively, and net of $(4) million and $— million tax for the six months ended June 30, 2018 and 2017, respectively.

(3)	Net of $— million tax for both the three months ended June 30, 2018 and 2017, respectively, and net of $(1) million tax for both the six months ended June 30, 2018 and 2017.

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30, 2018			December 31, 2017⁽¹⁾
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	5		$	4
Customer receivables (less allowance for doubtful accounts of less than $1 and $1)⁽²⁾		223			297
Other receivables (less allowance for doubtful accounts of $1 at both dates)⁽²⁾		22			15
Affiliated receivables		31			10
Inventories		82			64
Gas imbalances⁽²⁾		62			46
Prepayments		86			112
Other		60			52
Total current assets		571			600
Investments		97			97
Property, Plant and Equipment
Property, plant and equipment		11,341			11,173
Accumulated depreciation and amortization		(3,111	)		(3,018	)
Total property, plant and equipment, net		8,230			8,155
Deferred Charges and Other Assets
Pension and other postretirement benefit assets⁽²⁾		1,907			1,828
Other⁽²⁾		1,278			1,260
Total deferred charges and other assets		3,185			3,088
Total assets	$	12,083		$	11,940

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

(2)	See Note 18 for amounts attributable to related parties.

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30, 2018			December 31, 2017⁽¹⁾
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Short-term debt	$	188		$	629
Accounts payable		97			193
Payables to affiliates		15			62
Affiliated current borrowings		56			18
Other⁽²⁾		406			439
Total current liabilities		762			1,341
Long-Term Debt		4,062			3,570
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		1,489			1,454
Regulatory liabilities		1,253			1,227
Other		189			185
Total deferred credits and other liabilities		2,931			2,866
Total liabilities		7,755			7,777
Commitments and Contingencies (see Note 16)
Equity
Membership interests		4,446			4,261
Accumulated other comprehensive loss		(118	)		(98	)
Total equity		4,328			4,163
Total liabilities and equity	$	12,083		$	11,940

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

(2)	See Note 18 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 OF EQUITY

(Unaudited)

	Membership Interests			AOCI			Total
(millions)
December 31, 2017	$	4,261		$	(98	)	$	4,163
Cumulative-effect of changes in accounting principles		29			(26	)		3
Net income		181						181
Distributions		(25	)					(25	)
Other comprehensive income, net of tax					6			6
June 30, 2018	$	4,446		$	(118	)	$	4,328

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

DOMINION ENERGY GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2018			2017
(millions)
Operating Activities
Net income	$	181		$	185
Adjustments to reconcile net income to net cash provided by operating activities:
Gains on sales of assets		(44	)		—
Charge associated with FERC-regulated plant disallowance		129			—
Depreciation and amortization		112			110
Deferred income taxes and investment tax credits		27			112
Other adjustments		4			(6	)
Changes in:
Accounts receivable		67			73
Affiliated receivables and payables		(68	)		(19	)
Inventories		(18	)		(12	)
Deferred purchased gas costs, net		8			11
Prepayments		26			18
Accounts payable		(101	)		(97	)
Accrued interest, payroll and taxes		(51	)		(52	)
Pension and other postretirement benefits		(72	)		(65	)
Other operating assets and liabilities		7			(3	)
Net cash provided by operating activities		207			255
Investing Activities
Plant construction and other property additions		(316	)		(309	)
Proceeds from assignments of shale development rights		44			—
Other		(6	)		(1	)
Net cash used in investing activities		(278	)		(310	)
Financing Activities
Issuance (repayment) of short-term debt, net		(441	)		155
Issuance of long-term debt		500			—
Issuance (repayment) of affiliated current borrowings, net		38			(94	)
Distribution payments to parent		(25	)		(15	)
Other		(2	)		—
Net cash provided by financing activities		70			46
Decrease in cash, restricted cash and equivalents		(1	)		(9	)
Cash, restricted cash and equivalents at beginning of period		30			43
Cash, restricted cash and equivalents at end of period	$	29		$	34
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	51		$	44

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.

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 June 30, 2018, their results of operations for the three and six months ended June 30, 2018 and 2017, their cash flows for the six months ended June 30, 2018 and 2017, Dominion Energy’s changes in equity for the six months ended June 30, 2018 and 2017 and Virginia Power and Dominion Energy Gas’ changes in equity for the six months ended June 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 June 30, 2018, Dominion Energy owns the general partner, 60.9% of the common units and 37.5% of the convertible preferred interests in Dominion Energy Midstream. The public’s ownership interest in Dominion Energy Midstream is reflected as noncontrolling interest in Dominion Energy’s Consolidated Financial Statements. Also, at June 30, 2018, Dominion Energy owns 50% of the units in and consolidates Four Brothers and Three Cedars. NRG’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 June 30, 2018 nor are expected to occur in the remainder of 2018.

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 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 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, there 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.

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 and gains and losses from derivative instruments not subject to hedge accounting.

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 provided by (used in) investing activities for the six months ended June 30, 2017, which had been previously reported as $4 million and $(11) million, respectively. There was no impact to Virginia Power for the six months ended June 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 six months ended June 30, 2018 and 2017:

	Cash, Restricted Cash and Equivalents at End of Period				Cash, Restricted Cash and Equivalents at Beginning of Period
	June 30, 2018		June 30, 2017		December 31, 2017		December 31, 2016
(millions)
Dominion Energy
Cash and cash equivalents	$	190	$	260	$	120	$	261
Restricted cash and equivalents⁽¹⁾		164		64		65		61
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	354	$	324	$	185	$	322
Virginia Power
Cash and cash equivalents	$	20	$	44	$	14	$	11
Restricted cash and equivalents⁽¹⁾		10		—		10		—
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	30	$	44	$	24	$	11
Dominion Energy Gas
Cash and cash equivalents	$	5	$	4	$	4	$	23
Restricted cash and equivalents ⁽¹⁾		24		30		26		20
Cash, restricted cash and equivalents shown in the Consolidated Statements of Cash Flows	$	29	$	34	$	30	$	43

(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 between distributions from equity method affiliates to other adjustments from operating activities, which were previously reported as $(72) million for the six months ended June 30, 2017. There was no impact to Dominion Energy Gas for the six months ended June 30, 2017.

Property, Plant and Equipment

In the second quarter of 2018, Virginia Power recorded an adjustment for the retroactive application of depreciation rates for regulated nuclear plants to comply with Virginia Commission requirements. This adjustment resulted in a decrease of $46 million ($36 million after-tax) in depreciation expense in Virginia Power’s Consolidated Statements of Income. This revision is expected to decrease annual depreciation 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 in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income.

•

Debt securities classified as available-for-sale securities include all other debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments 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 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, the cost basis of the security is based on the specific identification method.

Equity securities with readily determinable fair values include securities held by Dominion Energy in rabbi trusts associated with certain deferred compensation plans and securities held by Dominion Energy and Virginia Power in the nuclear decommissioning trusts. Dominion Energy and Virginia Power record all equity securities with a readily determinable fair value, or for which they are permitted to estimate fair value using NAV (or its equivalent), at fair value in nuclear decommissioning trust funds and other investments in the Consolidated Balance Sheets. However, Dominion Energy and Virginia Power may elect a measurement alternative for equity securities without a readily determinable fair value. Under the measurement alternative, equity securities are reported at cost minus impairment, if any, plus or minus changes resulting from observable price changes in orderly transactions for the identical or a similar investment of the same issuer. Dominion Energy and Virginia Power qualitatively assess equity securities reported using the measurement alternative to determine whether an investment is impaired on an ongoing basis. Net realized and unrealized gains and losses on equity securities held in Virginia Power’s nuclear decommissioning trusts are 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.

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

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 recorded offsetting operating revenue and other energy-related purchases of $25 million and $50 million in the Consolidated Statements of Income for non-cash consideration for performing processing and fractionation services related to NGLs for the three and six months ended June 30, 2018, respectively. No such amounts were recorded during the three and six months ended June 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 $31 million and $63 million, respectively, and Dominion Energy Gas were $24 million and $48 million, respectively, recorded in the Consolidated Statements of Income for the three and six months ended June 30, 2017.

Financial Instruments

In January 2016, the FASB issued revised accounting guidance for the recognition, measurement, presentation and disclosure of financial instruments. The guidance became effective for the Companies’ interim and annual reporting periods beginning January 1, 2018 and 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 of regulatory deferrals, of $45 million ($36 million after-tax) and unrealized losses on equity securities, net of regulatory deferrals, of $2 million ($2 million after-tax) in other income in the Consolidated Statements of Income for the three and six months ended June 30, 2018, respectively, resulting in a $0.06 gain per share for the three months ended June 30, 2018. There was no impact to per share amounts at Dominion Energy for the six months ended June 30, 2018. Virginia Power recorded unrealized gains on equity securities, net of regulatory deferrals, of $6 million ($5 million after-tax) and unrealized losses on equity securities, net of regulatory deferrals, of $2 million ($2 million after-tax), respectively, in other income in the Consolidated Statements of Income for the three and six months ended June 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 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 six months ended June 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 June 30, 2017 were $779 million and $60 million, respectively, and were $1.5 billion and $176 million for the six months ended June 30, 2017, respectively. Dominion Energy Gas’ other operations and maintenance expense and other income for the three months ended June 30, 2017 were $126 million and $5 million, respectively, and were $259 million and $10 million for the six months ended June 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. The Companies adopted this guidance for interim and annual reporting periods beginning January 1, 2018 on a prospective basis. In connection with the adoption of this 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 of $26 million from AOCI to membership interests. The amounts reclassified reflect the reduction in the federal income tax rate, and the federal benefit of state income taxes, on the components of the Companies’ AOCI.

Note 3. Acquisitions and Dispositions

Dominion Energy

Proposed Acquisition of SCANA

Under the terms of the SCANA Merger Agreement announced in January 2018, Dominion Energy has agreed to issue 0.6690 shares of Dominion Energy common stock for each share of SCANA common stock upon closing. In addition, 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 related to the V.C. Summer Units 2 and 3 new nuclear development project and approximately $180 million to purchase the Columbia Energy Center power station. In addition, SCANA’s debt, which currently totals approximately $7.0 billion, is expected to remain outstanding.

The transaction requires approval of SCANA’s shareholders, FERC, applicable state commissions 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 termination of the waiting period under the Hart-Scott-Rodino Act. Also in February 2018, Dominion Energy and SCANA filed 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. 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, conditions 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 termination of the SCANA Merger Agreement under specified circumstances, Dominion Energy would be required to pay a termination fee of $280 million to SCANA and SCANA would be required to pay Dominion Energy a termination fee of $240 million. Subject to receipt of required regulatory approvals and meeting closing conditions, Dominion Energy targets closing by the end of 2018.

Wholly-Owned Merchant Solar Projects

In August 2016, Dominion Energy entered into an agreement to acquire 100% of the equity interests of two solar projects 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 allocated to property, plant and equipment. The facility commenced commercial operations in June 2017, at a cost of $78 million, including the initial acquisition cost, 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 have been executed for all of the projects described above. These projects are included in Power Generation. Dominion Energy has claimed or will claim federal investment tax credits on these solar projects.

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 June 30,		Six Months Ended June 30,
	2018		2018
(millions)
Dominion Energy
Regulated electric sales:
Residential	$	788	$	1,605
Commercial		636		1,160
Industrial		121		228
Government and other retail		210		423
Wholesale		23		65
Nonregulated electric sales		282		700
Regulated gas sales:
Residential		116		480
Commercial		34		137
Other		1		11
Nonregulated gas sales		9		97
Regulated gas transportation and storage:
FERC-regulated		272		534
State-regulated		144		334
Nonregulated gas transportation and storage		124		124
Other regulated revenues		44		94
Other nonregulated revenues⁽¹⁾⁽²⁾		141		277
Total operating revenue from contracts with customers		2,945		6,269
Other revenues		143		285
Total operating revenue	$	3,088	$	6,554
Virginia Power
Regulated electric sales:
Residential	$	788	$	1,605
Commercial		636		1,160
Industrial		121		228
Government and other retail		210		423
Wholesale		23		65
Other regulated revenues		33		65
Other nonregulated revenues⁽¹⁾		18		31
Total operating revenue from contracts with customers	$	1,829	$	3,577
Dominion Energy Gas
Regulated gas sales:
Residential	$	13	$	42
Other		2		9
Nonregulated gas sales⁽¹⁾		1		3
Regulated gas transportation and storage:
FERC-regulated⁽¹⁾		183		382
State-regulated⁽¹⁾		139		319
NGL revenue⁽¹⁾⁽²⁾		50		104
Management service revenue⁽¹⁾		60		107
Other regulated revenues⁽¹⁾		4		12
Other nonregulated revenues⁽¹⁾		4		6
Total operating revenue from contracts with customers		456		984
Other revenues⁽¹⁾		3		1
Total operating revenue	$	459	$	985

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

(2)

Amounts above include $33 million and $21 million for the three months ended June 30, 2018, and $63 million and $47 million for the six months ended June 30, 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.

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

Revenue expected to be recognized on multi-year contracts in place at June 30, 2018	2018		2019		2020		2021		2022		Thereafter		Total
(millions)
Dominion Energy	$	851	$	1,686	$	1,578	$	1,466	$	1,335	$	15,240	$	22,156
Virginia Power		11		21		3		1		—		—		36
Dominion Energy Gas		324		633		570		485		394		2,168		4,574

Contract assets represent an entity’s right to consideration in exchange for goods and services that the entity has transferred to a customer. At both June 30, 2018 and December 31, 2017, Dominion Energy’s contract asset balances were $46 million. Dominion Energy Gas’ contract asset balances were $64 million and $66 million at June 30, 2018 and December 31, 2017, respectively. Dominion Energy and Dominion Energy Gas’ contract assets are recorded in other deferred charges and other assets in the Consolidated Balance Sheets. Contract liabilities represent an entity’s obligation to transfer goods or services to a customer for which the entity has received consideration, or the amount that is due, from the customer. At June 30, 2018 and December 31, 2017, Dominion Energy’s contract liability balances were $71 million and $132 million, respectively. At June 30, 2018 and December 31, 2017, Virginia Power’s contract liability balances were $25 million and $50 million, respectively. At June 30, 2018 and December 31, 2017, Dominion Energy Gas’ contract liability balances were $14 million and $41 million, respectively. During the six months ended June 30, 2018, Dominion Energy, Virginia Power and Dominion Energy Gas recognized revenue of $88 million, $21 million and $40 million, respectively, from the beginning contract liability balances as the Companies fulfilled their obligations to provide service to their customers. The Companies’ contract liabilities are recorded in other current liabilities and other deferred credits and other liabilities in the Consolidated Balance Sheets.

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

	Three Months Ended June 30,		Six Months Ended June 30,
	2017		2017
(millions)
Dominion Energy
Electric sales:
Regulated	$	1,716	$	3,482
Nonregulated		307		734
Gas sales:
Regulated		151		599
Nonregulated		110		254
Gas transportation and storage		430		922
Other		99		206
Total operating revenue	$	2,813	$	6,197
Virginia Power
Regulated electric sales	$	1,716	$	3,482
Other		31		96
Total operating revenue	$	1,747	$	3,578
Dominion Energy Gas
Gas sales:
Regulated	$	15	$	47
Nonregulated		8		10
Gas transportation and storage		342		738
Other		57		117
Total operating revenue	$	422	$	912

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
Six Months Ended June 30,	2018			2017			2018			2017			2018			2017
U.S. statutory rate		21.0	%		35.0	%		21.0	%		35.0	%		21.0	%		35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit		3.8			2.8			4.5			3.7			3.6			1.5
Investment tax credits		(0.9	)		(5.5	)		(1.4	)		(0.8	)		—			—
Production tax credits		(0.7	)		(0.8	)		(0.7	)		(0.5	)		—			—
Reversal of excess deferred income taxes		(1.5	)		—			(2.0	)		—			(1.2	)		—
State legislative change		(1.6	)		—			—			—			0.3			—
AFUDC - equity		(1.0	)		(1.4	)		(0.5	)		(0.6	)		(0.4	)		(1.0	)
Other, net		(1.0	)		(2.6	)		0.3			(0.1	)		0.2			—
Effective tax rate		18.1	%		27.5	%		21.2	%		36.7	%		23.5	%		35.5	%

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 six months ended June 30, 2018, the Companies have recorded an estimate of the portion of excess deferred income tax amortization expected to occur in 2018. 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, 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, Dominion Energy and Dominion Energy Gas’ effective tax rates reflect the impacts of a state legislative change enacted in 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 June 30, 2018, there have been no changes to the provisional amounts recorded at December 31, 2017. 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 the impacts of the 2017 Tax Reform Act.

As of June 30, 2018, there have been no material changes in the Companies’ unrecognized tax benefits or possible changes that could reasonably be expected to occur during the next twelve months. See Note 5 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, for a discussion of these unrecognized tax benefits.

Note 6. Earnings Per Share

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
(millions, except EPS)
Net income attributable to Dominion Energy	$	449	$	390	$	952	$	1,022
Average shares of common stock outstanding – Basic		652.8		629.2		651.6		628.7
Net effect of dilutive securities		0.3		—		0.2		—
Average shares of common stock outstanding – Diluted		653.1		629.2		651.8		628.7
Earnings Per Common Share – Basic	$	0.69	$	0.62	$	1.46	$	1.63
Earnings Per Common Share – Diluted	$	0.69	$	0.62	$	1.46	$	1.63

The 2014 Equity Units were potentially dilutive securities, but were excluded from the calculation of diluted EPS for the three and six months ended June 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 six months ended June 30, 2018 and 2017, as the dilutive stock price threshold was not met. The Dominion Energy Midstream convertible preferred units are potentially dilutive securities but had no effect on the calculation of diluted EPS for the three and six months ended June 30, 2018 and 2017. In calculating diluted EPS in connection with the Dominion Energy Midstream convertible preferred units, Dominion Energy applies the if-converted method. The forward sales agreements, effective April 2018, are potentially dilutive securities but had no effect on the calculation of diluted EPS for the three and six months ended June 30, 2018. See Note 15 for more information regarding the forward sales agreements. In calculating diluted EPS in connection with the forward sales agreements, Dominion Energy applies the treasury stock 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
(millions)
Three Months Ended June 30, 2018
Beginning balance	$	(248	)	$	3		$	(1,303	)	$	(3	)	$	(1,551	)
Other comprehensive income before reclassifications: gains (losses)		(33	)		(5	)		—			1			(37	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		33			—			17			—			50
Net current period other comprehensive income (loss)		—			(5	)		17			1			13
Ending balance	$	(248	)	$	(2	)	$	(1,286	)	$	(2	)	$	(1,538	)
Three Months Ended June 30, 2017
Beginning balance	$	(260	)	$	599		$	(1,069	)	$	(5	)	$	(735	)
Other comprehensive income before reclassifications: gains (losses)		28			35			—			1			64
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(18	)		(4	)		11			—			(11	)
Net current period other comprehensive income (loss)		10			31			11			1			53
Ending balance	$	(250	)	$	630		$	(1,058	)	$	(4	)	$	(682	)
Six Months Ended June 30, 2018
Beginning balance	$	(302	)	$	747		$	(1,101	)	$	(3	)	$	(659	)
Other comprehensive income before reclassifications: gains (losses)		78			(18	)		—			1			61
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		41			1			42			—			84
Net current period other comprehensive income (loss)		119			(17	)		42			1			145
Cumulative-effect of changes in accounting principle		(64	)		(732	)		(227	)		—			(1,023	)
Less other comprehensive income attributable to noncontrolling interest		1			—			—			—			1
Ending balance	$	(248	)	$	(2	)	$	(1,286	)	$	(2	)	$	(1,538	)
Six Months Ended June 30, 2017
Beginning balance	$	(280	)	$	569		$	(1,082	)	$	(6	)	$	(799	)
Other comprehensive income before reclassifications: gains (losses)		71			93			—			2			166
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(41	)		(32	)		24			—			(49	)
Net current period other comprehensive income (loss)		30			61			24			2			117
Ending balance	$	(250	)	$	630		$	(1,058	)	$	(4	)	$	(682	)

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

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

Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Three Months Ended June 30, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	16		Operating revenue
Interest rate contracts		12		Interest and related charges
Foreign currency contracts		16		Other income
Total		44
Tax		(11	)	Income tax expense
Total, net of tax	$	33
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	1		Other income
Total		1
Tax		(1	)	Income tax expense
Total, net of tax	$	—
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(5	)	Other income
Amortization of actuarial losses		29		Other income
Total		24
Tax		(7	)	Income tax expense
Total, net of tax	$	17
Three Months Ended June 30, 2017
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(19	)	Operating revenue
		(2	)	Electric fuel and other energy-related purchases
Interest rate contracts		11		Interest and related charges
Foreign currency contracts		(19	)	Other income
Total		(29	)
Tax		11		Income tax expense
Total, net of tax	$	(18	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(11	)	Other income
Impairment		5		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		(10	)	Income tax expense
Total, net of tax	$	11
Six Months Ended June 30, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	28		Operating revenue
		2		Purchased gas
		(7	)	Electric fuel and other energy-related purchases
Interest rate contracts		24		Interest and related charges

Foreign currency contracts		8		Other income
Total		55
Tax		(14	)	Income tax expense
Total, net of tax	$	41
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	2		Other income
Total		2
Tax		(1	)	Income tax expense
Total, net of tax	$	1
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(11	)	Other income
Amortization of actuarial losses		61		Other income
Total		50
Tax		(8	)	Income tax expense
Total, net of tax	$	42
Six Months Ended June 30, 2017
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(81	)	Operating revenue
		(2	)	Electric fuel and other energy-related purchases
Interest rate contracts		23		Interest and related charges
Foreign currency contracts		(6	)	Other income
Total		(66	)
Tax		25		Income tax expense
Total, net of tax	$	(41	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(64	)	Other income
Impairment		14		Other income
Total		(50	)
Tax		18		Income tax expense
Total, net of tax	$	(32	)
Unrecognized pension and other postretirement benefit costs:
Amortization of prior-service costs (credits)	$	(9	)	Other income
Amortization of actuarial losses		51		Other income
Total		42
Tax		(18	)	Income tax expense
Total, net of tax	$	24

Virginia Power

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

	Deferred gains and losses on derivatives- hedging activities			Unrealized gains and losses on investment securities			Total
(millions)
Three Months Ended June 30, 2018
Beginning balance	$	(10	)	$	1		$	(9	)
Other comprehensive income before reclassifications: gains (losses)		2			(2	)		—
Amounts reclassified from AOCI: (gains) losses		—			—			—
Net current period other comprehensive income (loss)		2			(2	)		—
Ending balance	$	(8	)	$	(1	)	$	(9	)
Three Months Ended June 30, 2017
Beginning balance	$	(8	)	$	58		$	50
Other comprehensive income before reclassifications: gains (losses)		(3	)		4			1
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		1			(1	)		—
Net current period other comprehensive income (loss)		(2	)		3			1
Ending balance	$	(10	)	$	61		$	51
Six Months Ended June 30, 2018
Beginning balance	$	(12	)	$	74		$	62
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
Cumulative-effect of changes in accounting principle		(3	)		(73	)		(76	)
Ending balance	$	(8	)	$	(1	)	$	(9	)
Six Months Ended June 30, 2017
Beginning balance	$	(8	)	$	54		$	46
Other comprehensive income before reclassifications: gains (losses)		(3	)		11			8
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		1			(4	)		(3	)
Net current period other comprehensive income (loss)		(2	)		7			5
Ending balance	$	(10	)	$	61		$	51

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

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

Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Three Months Ended June 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	$	(1	)	Other income
Total		(1	)
Tax		—		Income tax expense
Total, net of tax	$	(1	)
Six Months Ended June 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	$	(7	)	Other income
Impairment		1		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
(millions)
Three Months Ended June 30, 2018
Beginning balance	$	(18	)	$	(95	)	$	(113	)
Other comprehensive income before reclassifications: gains (losses)		(20	)		—			(20	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		14			1			15
Net current period other comprehensive income (loss)		(6	)		1			(5	)
Ending balance	$	(24	)	$	(94	)	$	(118	)
Three Months Ended June 30, 2017
Beginning balance	$	(22	)	$	(99	)	$	(121	)
Other comprehensive income before reclassifications: gains (losses)		11			—			11
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(12	)		2			(10	)
Net current period other comprehensive income (loss)		(1	)		2			1
Ending balance	$	(23	)	$	(97	)	$	(120	)
Six Months Ended June 30, 2018
Beginning balance	$	(23	)	$	(75	)	$	(98	)
Other comprehensive income before reclassifications: gains (losses)		(7	)		—			(7	)
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		11			2			13
Net current period other comprehensive income (loss)		4			2			6
Cumulative-effect of changes in accounting principle		(5	)		(21	)		(26	)
Ending balance	$	(24	)	$	(94	)	$	(118	)
Six Months Ended June 30, 2017
Beginning balance	$	(24	)	$	(99	)	$	(123	)
Other comprehensive income before reclassifications: gains (losses)		2			—			2
Amounts reclassified from AOCI: (gains) losses⁽¹⁾		(1	)		2			1
Net current period other comprehensive income (loss)		1			2			3
Ending balance	$	(23	)	$	(97	)	$	(120	)

(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
(millions)
Three Months Ended June 30, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	2		Operating revenue
Interest rate contracts		1		Interest and related charges
Foreign currency contracts		16		Other income
Total		19
Tax		(5	)	Income tax expense
Total, net of tax	$	14
Unrecognized pension costs:
Actuarial losses	$	1		Other income
Total		1
Tax		—		Income tax expense
Total, net of tax	$	1
Three Months Ended June 30, 2017
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
Interest rate contracts		1		Interest and related charges
Foreign currency contracts		(19	)	Other income
Total		(19	)
Tax		7		Income tax expense
Total, net of tax	$	(12	)
Unrecognized pension costs:
Actuarial losses	$	2		Other income
Total		2
Tax		—		Income tax expense
Total, net of tax	$	2
Six Months Ended June 30, 2018
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	5		Operating revenue
Interest rate contracts		2		Interest and related charges
Foreign currency contracts		8		Other income
Total		15
Tax		(4	)	Income tax expense
Total, net of tax	$	11
Unrecognized pension costs:
Actuarial losses	$	3		Other income
Total		3
Tax		(1	)	Income tax expense
Total, net of tax	$	2
Six Months Ended June 30, 2017
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	3		Operating revenue
Interest rate contracts		2		Interest and related charges
Foreign currency contracts		(6	)	Other income
Total		(1	)
Tax		—		Income tax expense

Total, net of tax	$	(1	)
Unrecognized pension costs:
Actuarial losses	$	3		Other income
Total		3
Tax		(1	)	Income tax expense
Total, net of tax	$	2

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 June 30, 2018. 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⁾
Assets
Physical and financial forwards and futures:
Natural gas⁽²⁾	$	90	Discounted cash flow	Market price (per Dth)	⁽³⁾	(1) - 6		—
FTRs		7	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 6		—
Physical options:
Natural gas		1	Option model	Market price (per Dth)	⁽³⁾	2 - 6		3
				Price volatility	⁽⁴⁾	13% - 35%		23	%
Electricity		24	Option model	Market price (per MWh)	⁽³⁾	24 - 51		37
				Price volatility	⁽⁴⁾	4% - 62%		29	%
Total assets	$	122
Liabilities
Financial forwards:
FTRs	$	3	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 6		1
Total liabilities	$	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)

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
(millions)
At June 30, 2018
Assets
Derivatives:
Commodity	$	—	$	37	$	122	$	159
Interest rate		—		58		—		58
Foreign currency		—		33		—		33
Investments⁽¹⁾:
Equity securities:
U.S.		3,529		—		—		3,529
Fixed income securities:
Corporate debt instruments		—		445		—		445
Government securities		270		837		—		1,107
Cash equivalents and other		14		—		—		14
Total assets	$	3,813	$	1,410	$	122	$	5,345
Liabilities
Derivatives:
Commodity	$	—	$	52	$	3	$	55
Interest rate		—		58		—		58
Foreign currency		—		5		—		5
Total liabilities	$	—	$	115	$	3	$	118
At December 31, 2017
Assets
Derivatives:
Commodity	$	—	$	101	$	157	$	258
Interest rate		—		17		—		17
Foreign currency		—		32		—		32
Investments⁽¹⁾:
Equity securities:
U.S.		3,493		—		—		3,493
Fixed income securities:
Corporate debt instruments		—		444		—		444
Government securities		307		794		—		1,101
Cash equivalents and other		34		—		—		34
Total assets	$	3,834	$	1,388	$	157	$	5,379
Liabilities
Derivatives:
Commodity	$	—	$	190	$	7	$	197
Interest rate		—		85		—		85
Foreign currency		—		2		—		2
Total liabilities	$	—	$	277	$	7	$	284

(1)

Includes investments held in the nuclear decommissioning and rabbi trusts. Excludes $211 million and $88 million of assets at June 30, 2018 and December 31, 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2018			2017			2018			2017
(millions)
Beginning balance	$	120		$	130		$	150		$	139
Total realized and unrealized gains (losses):
Included in earnings		(2	)		(10	)		(20	)		(25	)
Included in other comprehensive income		—			—			1			—
Included in regulatory assets/liabilities		11			32			(10	)		23
Settlements		(10	)		—			(3	)		12
Transfers out of Level 3		—			—			1			3
Ending balance	$	119		$	152		$	119		$	152

The following table presents Dominion Energy’s classification of gains and losses included in earnings in the Level 3 fair value category. The unrealized gains or losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date were not material for the three and six months ended June 30, 2018 and 2017.

	Operating Revenue			Electric Fuel and Other Energy-Related Purchases			Total
(millions)
Three Months Ended June 30, 2018
Total gains (losses) included in earnings	$	—		$	(2	)	$	(2	)
Three Months Ended June 30, 2017
Total gains (losses) included in earnings	$	—		$	(10	)	$	(10	)
Six Months Ended June 30, 2018
Total gains (losses) included in earnings	$	(1	)	$	(19	)	$	(20	)
Six Months Ended June 30, 2017
Total gains (losses) included in earnings	$	—		$	(25	)	$	(25	)

Virginia Power

The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at June 30, 2018. 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⁾
Assets
Physical and financial forwards and futures:
Natural gas⁽²⁾	$	86	Discounted cash flow	Market price (per Dth)	⁽³⁾	(1) - 6		(1	)
FTRs		7	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 6		—
Physical options:
Natural gas		1	Option model	Market price (per Dth)	⁽³⁾	2 - 6		3
				Price volatility	⁽⁴⁾	13% - 35%		23	%
Electricity		24	Option model	Market price (per MWh)	⁽³⁾	24 - 51		37
				Price volatility	⁽⁴⁾	4% - 62%		29	%
Total assets	$	118
Liabilities
Financial forwards:
FTRs	$	3	Discounted cash flow	Market price (per MWh)	⁽³⁾	(1) - 6		1
Total liabilities	$	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
(millions)
At June 30, 2018
Assets
Derivatives:
Commodity	$	—	$	8	$	118	$	126
Interest rate		—		21		—		21
Investments⁽¹⁾:
Equity securities:
U.S.		1,584		—		—		1,584
Fixed income securities:
Corporate debt instruments		—		227		—		227
Government securities		164		328		—		492
Cash equivalents and other		3		—		—		3
Total assets	$	1,751	$	584	$	118	$	2,453
Liabilities
Derivatives:
Commodity	$	—	$	5	$	3	$	8
Interest rate		—		6		—		6
Total liabilities	$	—	$	11	$	3	$	14
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
Total liabilities	$	—	$	61	$	5	$	66

(1)

Includes investments held in the nuclear decommissioning trusts. Excludes $171 million and $27 million of assets at June 30, 2018 and December 31, 2017, respectively, measured at fair value using NAV (or its equivalent) as a practical expedient which are not required to be categorized in the fair value hierarchy.

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

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2018			2017			2018			2017
(millions)
Beginning balance	$	117		$	132		$	147		$	143
Total realized and unrealized gains (losses):
Included in earnings		(2	)		(10	)		(19	)		(25	)
Included in regulatory assets/liabilities		8			31			(11	)		23
Settlements		(8	)		(1	)		(2	)		11
Ending balance	$	115		$	152		$	115		$	152

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 six months ended June 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 six months ended June 30, 2018 and 2017.

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
(millions)
At June 30, 2018
Assets
Interest rate	$	—	$	1	$	—	$	1
Foreign currency		—		33		—		33
Total assets	$	—	$	34	$	—	$	34
Liabilities
Commodity	$	—	$	7	$	—	$	7
Interest rate		—		4		—		4
Foreign currency		—		5		—		5
Total liabilities	$	—	$	16	$	—	$	16
At December 31, 2017
Assets
Foreign currency	$	—	$	32	$	—	$	32
Total assets	$	—	$	32	$	—	$	32
Liabilities
Commodity	$	—	$	4	$	2	$	6
Foreign currency		—		2		—		2
Total liabilities	$	—	$	6	$	2	$	8

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 June 30, 2018 and 2017.

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

There were no gains or losses included in earnings in the Level 3 fair value category for the six months ended June 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 six months ended June 30, 2018 and 2017.

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:

	June 30, 2018				December 31, 2017
	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⁾	$	29,629	$	30,779	$	28,666	$	31,233
Junior subordinated notes⁽³⁾		3,981		4,016		3,981		4,102
Remarketable subordinated notes⁽³⁾		1,382		1,294		1,379		1,446
Credit facility borrowings		73		73		—		—
Virginia Power
Long-term debt, including securities due within one year⁽³⁾	$	11,091	$	11,799	$	11,346	$	12,842
Dominion Energy Gas
Long-term debt, including securities due within one year⁽⁴⁾	$	4,062	$	4,094	$	3,570	$	3,719

(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 June 30, 2018 and December 31, 2017, includes the valuation of certain fair value hedges associated with fixed rate debt of $(61) million and $(22) 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 17 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 and after the effects of offsetting:

	June 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)
Commodity contracts:
Over-the-counter	$	130	$	—	$	130	$	174	$	—	$	174
Exchange		21		—		21		80		—		80
Interest rate contracts:
Over-the-counter		58		—		58		17		—		17
Foreign currency contracts:
Over-the-counter		33		—		33		32		—		32
Total derivatives, subject to a master netting or similar arrangement		242		—		242		303		—		303
Total derivatives, not subject to a master netting or similar arrangement		8		—		8		4		—		4
Total	$	250	$	—	$	250	$	307	$	—	$	307

			June 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	$	130		$	7	$	—	$	123	$	174		$	9	$	—	$	165
Exchange		21			21		—		—		80			80		—		—
Interest rate contracts:
Over-the-counter		58			9		—		49		17			8		—		9
Foreign currency contracts:
Over-the-counter		33			5		—		28		32			2		—		30
Total	$	242		$	42	$	—	$	200	$	303		$	99	$	—	$	204

	June 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	$	23	$	—	$	23	$	76	$	—	$	76
Exchange		32		—		32		120		—		120
Interest rate contracts:
Over-the-counter		58		—		58		85		—		85
Foreign currency contracts:
Over-the-counter		5		—		5		2		—		2
Total derivatives, subject to a master netting or similar arrangement		118		—		118		283		—		283
Total derivatives, not subject to a master netting or similar arrangement		—		—		—		1		—		1
Total	$	118	$	—	$	118	$	284	$	—	$	284

			June 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	$	23		$	7	$	—	$	16	$	76	$	9	$	6	$	61
Exchange		32			21		11		—		120		80		40		—
Interest rate contracts:
Over-the-counter		58			9		—		49		85		8		—		77
Foreign currency contracts:
Over-the-counter		5			5		—		—		2		2		—		—
Total	$	118		$	42	$	11	$	65	$	283	$	99	$	46	$	138

Volumes

The following table presents the volume of Dominion Energy’s derivative activity at June 30, 2018. 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
Natural Gas (bcf):
Fixed price⁽¹⁾		75		24
Basis		214		600
Electricity (MWh):
Fixed price⁽¹⁾		10,566,074		677,760
FTRs		102,797,191		—
Liquids (Gal)⁽²⁾		51,019,800		—
Interest rate⁽³⁾	$	600,000,000	$	5,433,632,652
Foreign currency⁽³⁾⁽⁴⁾	$	—	$	280,000,000

(1)	Includes options.

(2)	Includes NGLs and oil.

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

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

Ineffectiveness and AOCI

For the three and six months ended June 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 June 30, 2018:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	—		$	1		37 months
Electricity		(9	)		(9	)	18 months
Other		(5	)		(5	)	9 months
Interest rate		(246	)		(9	)	378 months
Foreign currency		12			(4	)	96 months
Total	$	(248	)	$	(26	)

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 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
(millions)
June 30, 2018
ASSETS
Current Assets
Commodity	$	10	$	67	$	77
Interest rate		12		—		12
Total current derivative assets⁽¹⁾		22		67		89
Noncurrent Assets
Commodity		1		81		82
Interest rate		46		—		46
Foreign currency		33		—		33
Total noncurrent derivative assets⁽²⁾		80		81		161
Total derivative assets	$	102	$	148	$	250
LIABILITIES
Current Liabilities
Commodity	$	30	$	22	$	52
Interest rate		12		—		12
Foreign currency		5		—		5
Total current derivative liabilities⁽³⁾		47		22		69
Noncurrent Liabilities
Commodity		2		1		3
Interest rate		46		—		46
Total noncurrent derivative liabilities⁽⁴⁾		48		1		49
Total derivative liabilities	$	95	$	23	$	118
December 31, 2017
ASSETS
Current Assets
Commodity	$	5	$	158	$	163
Interest rate		6		—		6
Total current derivative assets⁽¹⁾		11		158		169
Noncurrent Assets
Commodity		—		95		95
Interest rate		11		—		11
Foreign currency		32		—		32
Total noncurrent derivative assets⁽²⁾		43		95		138
Total derivative assets	$	54	$	253	$	307
LIABILITIES
Current Liabilities
Commodity	$	103	$	92	$	195
Interest rate		53		—		53
Foreign currency		2		—		2
Total current derivative liabilities⁽³⁾		158		92		250
Noncurrent Liabilities
Commodity		1		1		2
Interest rate		32		—		32
Total noncurrent derivative liabilities⁽⁴⁾		33		1		34
Total derivative liabilities	$	191	$	93	$	284

(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:

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⁾
(millions)
Three Months Ended June 30, 2018
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	(16	)
Total commodity	$	(39	)	$	(16	)	$	—
Interest rate⁽³⁾		9			(12	)		25
Foreign currency⁽⁴⁾		(14	)		(16	)		—
Total	$	(44	)	$	(44	)	$	25
Three Months Ended June 30, 2017
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	19
Electric fuel and other energy-related purchases					2
Total commodity	$	44		$	21		$	—
Interest rate⁽³⁾		(15	)		(11	)		(42	)
Foreign currency⁽⁴⁾		16			19			—
Total	$	45		$	29		$	(42	)
Six Months Ended June 30, 2018
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	(28	)
Purchased gas					(2	)
Electric fuel and other energy-related purchases					7
Total commodity	$	58		$	(23	)	$	—
Interest rate⁽³⁾		47			(24	)		93
Foreign currency⁽⁴⁾		(1	)		(8	)		—
Total	$	104		$	(55	)	$	93
Six Months Ended June 30, 2017
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	81
Electric fuel and other energy-related purchases					2
Total commodity	$	131		$	83		$	—
Interest rate⁽³⁾		(14	)		(23	)		(34	)
Foreign currency⁽⁴⁾		(2	)		6			—
Total	$	115		$	66		$	(34	)

(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⁾
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2018			2017			2018			2017
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	(9	)	$	10		$	(3	)	$	14
Purchased gas		4			(8	)		4			8
Electric fuel and other energy-related purchases		(3	)		(8	)		(16	)		(32	)
Other operations & maintenance		—			(1	)		—			(1	)
Total	$	(8	)	$	(7	)	$	(15	)	$	(11	)

(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 and after the effects of offsetting:

	June 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)
Commodity contracts:
Over-the-counter	$	117	$	—	$	117	$	155	$	—	$	155
Interest rate contracts:
Over-the-counter		21		—		21		—		—		—
Total derivatives, subject to a master netting or similar arrangement		138		—		138		155		—		155
Total derivatives, not subject to a master netting or similar arrangement		9		—		9		11		—		11
Total	$	147	$	—	$	147	$	166	$	—	$	166

			June 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	$	117	$	3	$	—	$	114	$	155	$	4	$	—	$	151
Interest rate contracts:
Over-the-counter		21		3		—		18		—		—		—		—
Total	$	138	$	6	$	—	$	132	$	155	$	4	$	—	$	151

	June 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	$	3	$	—	$	3	$	4	$	—	$	4
Interest rate contracts:
Over-the-counter		6		—		6		57		—		57
Total derivatives, subject to a master netting or similar arrangement		9		—		9		61		—		61
Total derivatives, not subject to a master netting or similar arrangement		5		—		5		5		—		5
Total	$	14	$	—	$	14	$	66	$	—	$	66

			June 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	$	3	$	3	$	—	$	—	$	4	$	4	$	—	$	—
Interest rate contracts:
Over-the-counter		6		3		—		3		57		—		—		57
Total	$	9	$	6	$	—	$	3	$	61	$	4	$	—	$	57

Volumes

The following table presents the volume of Virginia Power’s derivative activity at June 30, 2018. 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
Natural Gas (bcf):
Fixed price⁽¹⁾		27		4
Basis		112		514
Electricity (MWh):
Fixed price⁽¹⁾		1,061,191		—
FTRs		101,284,984		—
Interest rate⁽²⁾	$	600,000,000	$	1,000,000,000

(1)	Includes options.

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

Ineffectiveness and AOCI

For the three and six months ended June 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 June 30, 2018:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(8	)	$	(1	)	378 months
Total	$	(8	)	$	(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
(millions)
June 30, 2018
ASSETS
Current Assets
Commodity	$	—	$	49	$	49
Interest rate		8		—		8
Total current derivative assets⁽¹⁾		8		49		57
Noncurrent Assets
Commodity		—		77		77
Interest rate		13		—		13
Total noncurrent derivative assets⁽²⁾		13		77		90
Total derivative assets	$	21	$	126	$	147
LIABILITIES
Current Liabilities
Commodity	$	—	$	8	$	8
Interest rate		4		—		4
Total current derivative liabilities⁽³⁾		4		8		12
Noncurrent Liabilities
Interest rate		2		—		2
Total noncurrent derivatives liabilities ⁽⁴⁾		2		—		2
Total derivative liabilities	$	6	$	8	$	14
December 31, 2017
ASSETS
Current Assets
Commodity	$	—	$	75	$	75
Total current derivative assets⁽¹⁾		—		75		75
Noncurrent Assets
Commodity		—		91		91
Total noncurrent derivative assets⁽²⁾		—		91		91
Total derivative assets	$	—	$	166	$	166
LIABILITIES
Current Liabilities
Commodity	$	—	$	9	$	9
Interest rate		44		—		44
Total current derivative liabilities⁽³⁾		44		9		53
Noncurrent Liabilities
Interest rate		13		—		13
Total noncurrent derivatives liabilities ⁽⁴⁾		13		—		13
Total derivative liabilities	$	57	$	9	$	66

(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⁾
(millions)
Three Months Ended June 30, 2018
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	2		$	—		$	25
Total	$	2		$	—		$	25
Three Months Ended June 30, 2017
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(5	)	$	(1	)	$	(42	)
Total	$	(5	)	$	(1	)	$	(42	)
Six Months Ended June 30, 2018
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	9		$	—		$	93
Total	$	9		$	—		$	93
Six Months Ended June 30, 2017
Derivative type and location of gains (losses):
Interest rate⁽³⁾	$	(5	)	$	(1	)	$	(34	)
Total	$	(5	)	$	(1	)	$	(34	)

(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⁾
	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2018			2017			2018			2017
(millions)
Derivative type and location of gains (losses):
Commodity⁽²⁾	$	(3	)	$	(7	)	$	(3	)	$	(24	)
Total	$	(3	)	$	(7	)	$	(3	)	$	(24	)

(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 and after the effects of offsetting.

	June 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	$	1	$	—	$	1	$	—	$	—	$	—
Foreign currency contracts:
Over-the-counter		33		—		33		32		—		32
Total derivatives, subject to a master netting or similar arrangement	$	34	$	—	$	34	$	32	$	—	$	32

			June 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	$	1		$	1	$	—	$	—	$	—	$	—	$	—	$	—
Foreign currency contracts:
Over-the-counter		33			5		—		28		32		2		—		30
Total	$	34		$	6	$	—	$	28	$	32	$	2	$	—	$	30

	June 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	$	7	$	—	$	7	$	6	$	—	$	6
Interest rate contracts:
Over-the-counter		4		—		4		—		—		—
Foreign currency contracts:
Over-the-counter		5		—		5		2		—		2
Total derivatives, subject to a master netting or similar arrangement	$	16	$	—	$	16	$	8	$	—	$	8

			June 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	$	7	$	—	$	—	$	7	$	6	$	—	$	—	$	6
Interest rate contracts:
Over-the-counter		4		1		—		3		—		—		—		—
Foreign currency contracts:
Over-the-counter		5		5		—		—		2		2		—		—
Total	$	16	$	6	$	—	$	10	$	8	$	2	$	—	$	6

Volumes

The following table presents the volume of Dominion Energy Gas’ derivative activity at June 30, 2018. 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
Natural Gas (bcf):
Basis		1		—
NGLs (Gal)		45,643,800		—
Interest rate⁽¹⁾	$	—	$	1,050,000,000
Foreign currency⁽¹⁾⁽²⁾	$	—	$	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 six months ended June 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 June 30, 2018:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
NGLs	$	(5	)	$	(5	)	9 months
Interest rate		(31	)		(4	)	318 months
Foreign currency		12			(4	)	96 months
Total	$	(24	)	$	(13	)

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
(millions)
June 30, 2018
ASSETS
Noncurrent Assets
Interest rate	$	1	$	—	$	1
Foreign currency		33		—		33
Total noncurrent derivative assets⁽¹⁾		34		—		34
Total derivative assets	$	34	$	—	$	34
LIABILITIES
Current Liabilities
Commodity	$	7	$	—	$	7
Interest rate		1		—		1
Foreign currency		5		—		5
Total current derivative liabilities⁽²⁾		13		—		13
Noncurrent Liabilities
Interest rate		3		—		3
Total noncurrent derivative liabilities⁽³⁾		3		—		3
Total derivative liabilities	$	16	$	—	$	16
December 31, 2017
ASSETS
Noncurrent Assets
Foreign currency	$	32	$	—	$	32
Total noncurrent derivative assets⁽¹⁾		32		—		32
Total derivative assets	$	32	$	—	$	32
LIABILITIES
Current Liabilities
Commodity	$	6	$	—	$	6
Foreign currency		2		—		2
Total current derivative liabilities⁽²⁾		8		—		8
Total derivative liabilities	$	8	$	—	$	8

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

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

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

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

Derivatives in cash flow hedging relationships	Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)⁽¹⁾			Amount of Gain (Loss) Reclassified From AOCI to Income
(millions)
Three Months Ended June 30, 2018
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(2	)
Total commodity	$	(10	)	$	(2	)
Interest rate⁽²⁾		(3	)		(1	)
Foreign currency⁽³⁾		(14	)		(16	)
Total	$	(27	)	$	(19	)
Three Months Ended June 30, 2017
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	1
Total commodity	$	2		$	1
Interest rate⁽²⁾		—			(1	)
Foreign currency⁽³⁾		16			19
Total	$	18		$	19
Six Months Ended June 30, 2018
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(5	)
Total commodity	$	(6	)	$	(5	)
Interest rate⁽²⁾		(3	)		(2	)
Foreign currency⁽³⁾		(1	)		(8	)
Total	$	(10	)	$	(15	)
Six Months Ended June 30, 2017
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	(3	)
Total commodity	$	4		$	(3	)
Interest rate⁽²⁾		—			(2	)
Foreign currency⁽³⁾		(1	)		6
Total	$	3		$	1

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

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

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

Note 10. Investments

Dominion Energy

Equity and Debt Securities

Rabbi Trust Securities

Equity and debt securities and cash equivalents in Dominion Energy’s rabbi trusts and classified as trading totaled $114 million and $112 million at June 30, 2018 and December 31, 2017, respectively.

Decommissioning Trust Securities

Dominion Energy holds equity and debt securities, 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
(millions)
June 30, 2018
Equity securities:⁽¹⁾
U.S.	$	1,695	$	1,896	$	(14	)		$	3,577
Fixed income securities:⁽²⁾
Corporate debt instruments		447		6		(8	)			445
Government securities		1,058		16		(14	)			1,060
Common/collective trust funds		72		—		—				72
Cash equivalents and other⁽³⁾		5		—		—				5
Total	$	3,277	$	1,918	$	(36	)	⁽⁴⁾	$	5,159
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 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.

(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 purchases of securities of $3 million at June 30, 2018 and pending sales of securities of $5 million at December 31, 2017.

(4)	The fair value of securities in an unrealized loss position was $900 million and $565 million at June 30, 2018 and December 31, 2017, 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 June 30, 2018			Six Months Ended June 30, 2018
Net gains recognized during the period	$	89		$	24
Less: Net gains recognized during the period on securities sold during the period		(16	)		(35	)
Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018⁽¹⁾	$	73		$	(11	)

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

The fair value of Dominion Energy’s debt securities with readily determinable fair values held in nuclear decommissioning trust funds at June 30, 2018 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	321
Due after one year through five years		327
Due after five years through ten years		353
Due after ten years		576
Total	$	1,577

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
(millions)
Proceeds from sales	$	425	$	363	$	844	$	1,119
Realized gains⁽¹⁾		36		23		72		117
Realized losses⁽¹⁾		23		16		42		36

(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 Dominion Energy were not material for the three and six months ended June 30, 2018 and 2017.

Virginia Power

Virginia Power holds equity and debt securities, 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
(millions)
June 30, 2018
Equity securities:⁽¹⁾
U.S.	$	837	$	861	$	(7	)		$	1,691
Fixed income securities:⁽²⁾
Corporate debt instruments		228		3		(4	)			227
Government securities		490		7		(5	)			492
Common/collective trust funds		32		—		—				32
Cash equivalents and other⁽³⁾		7		—		—				7
Total	$	1,594	$	871	$	(16	)	⁽⁴⁾	$	2,449
December 31, 2017
Equity securities:⁽²⁾
U.S.	$	734	$	831	$	—			$	1,565
Fixed income securities:⁽²⁾
Corporate debt instruments		216		8		—				224
Government securities		482		13		(2	)			493
Common/collective trust funds		27		—		—				27
Cost method investments		68		—		—				68
Cash equivalents and other⁽³⁾		22		—		—				22
Total	$	1,549	$	852	$	(2	)	⁽⁴⁾	$	2,399

(1)	Effective January 2018, 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.

(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 $5 million and $6 million at June 30, 2018 and December 31, 2017, respectively.

(4)	The fair value of securities in an unrealized loss position was $414 million and $234 million at June 30, 2018 and December 31, 2017, 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 June 30, 2018			Six Months Ended June 30, 2018
(millions)
Net gains recognized during the period	$	44		$	12
Less: Net gains recognized during the period on securities sold during the period		(8	)		(23	)
Unrealized gains (losses) recognized during the period on securities still held at June 30, 2018⁽¹⁾	$	36		$	(11	)

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

The fair value of Virginia Power’s debt securities with readily determinable fair values held in nuclear decommissioning trust funds at June 30, 2018 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	49
Due after one year through five years		158
Due after five years through ten years		216
Due after ten years		328
Total	$	751

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
(millions)
Proceeds from sales	$	196	$	168	$	414	$	498
Realized gains⁽¹⁾		15		10		33		55
Realized losses⁽¹⁾		7		8		12		18

(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 for the three and six months ended June 30, 2018 and 2017.

Equity Method Investments

Dominion Energy

Atlantic Coast Pipeline

Dominion Energy recorded contributions of $81 million and $85 million during the three months ended June 30, 2018 and 2017, respectively, and $159 million and $202 million during the six months ended June 30, 2018 and 2017, respectively, to Atlantic Coast Pipeline. At June 30, 2018, Dominion Energy had $33 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 $60 million and $30 million for the three months ended June 30, 2018 and 2017, respectively, and $106 million and $61 million for the six months ended June 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 $19 million and $12 million at June 30, 2018 and December 31, 2017, 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 16 for more information.

NedPower

Dominion Energy has a liability of $1 million and $17 million recorded to other deferred credits and other liabilities on the Consolidated Balance Sheets at June 30, 2018 and December 31, 2017, respectively, relating to its commitment to provide further financial support for NedPower.

Other

In July 2018, Dominion Energy entered into an agreement to sell its 25% limited partnership interest in Catalyst Old River Hydroelectric Limited Partnership, which is accounted for as an equity method investment with zero carrying value at June 30, 2018. The transaction is expected to close in the third quarter of 2018 with proceeds of approximately $90 million, subject to customary closing adjustments. As a result, Dominion Energy expects to recognize a gain of approximately $90 million ($65 million after-tax) in the third quarter of 2018.

Dominion Energy Gas

Iroquois

Dominion Energy Gas’ equity earnings totaled $14 million and $11 million for the six months ended June 30, 2018 and 2017, respectively. Dominion Energy Gas received distributions of $14 million and $11 million for the six months ended June 30, 2018 and 2017, respectively. At both June 30, 2018 and December 31, 2017, the carrying amount of Dominion Energy Gas’ investment of $95 million 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

Virginia Power

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 $1 million in operating revenue and $1 million in other income for the three months ended June 30, 2018 and 2017, respectively, and recorded $3 million in operating revenue and $8 million in other income for the six months ended June 30, 2018 and 2017, respectively, with $32 million remaining to be recognized ratably through 2023.

Dominion Energy Gas

Assignment of Shale Development Rights

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 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 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 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:

	June 30, 2018		December 31, 2017
(millions)
Dominion Energy
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	344	$	23
Deferred rate adjustment clause costs⁽²⁾		89		70
Deferred nuclear refueling outage costs⁽³⁾		76		54
Unrecovered gas costs⁽⁴⁾		3		38
Other		104		109
Regulatory assets-current		616		294
Unrecognized pension and other postretirement benefit costs⁽⁵⁾		1,296		1,336
Deferred rate adjustment clause costs⁽²⁾		372		401
PJM transmission rates⁽⁶⁾		237		222
Utility reform legislation⁽⁷⁾		174		147
Derivatives⁽⁸⁾		131		223
Other		185		151
Regulatory assets-noncurrent		2,395		2,480
Total regulatory assets	$	3,011	$	2,774
Regulatory liabilities:
Reserve for rate credits to electric utility customers⁽⁹⁾	$	200	$	—
Provision for future cost of removal and AROs⁽¹⁰⁾		101		101
Other		123		92
Regulatory liabilities-current⁽¹¹⁾		424		193
Income taxes refundable through future rates⁽¹²⁾		4,037		4,058
Provision for future cost of removal and AROs⁽¹⁰⁾		1,407		1,384
Nuclear decommissioning trust⁽¹³⁾		1,147		1,121
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁴⁾		84		—
Other		390		353
Regulatory liabilities-noncurrent		7,065		6,916
Total regulatory liabilities	$	7,489	$	7,109
Virginia Power
Regulatory assets:
Deferred cost of fuel used in electric generation⁽¹⁾	$	344	$	23
Deferred nuclear refueling outage costs⁽³⁾		76		54
Deferred rate adjustment clause costs⁽²⁾		56		56
Other		76		72
Regulatory assets-current		552		205
Deferred rate adjustment clause costs⁽²⁾		296		312
PJM transmission rates⁽⁶⁾		237		222
Derivatives⁽⁸⁾		98		190
Other		98		86
Regulatory assets-noncurrent		729		810
Total regulatory assets	$	1,281	$	1,015
Regulatory liabilities:
Reserve for rate credits to customers⁽⁹⁾	$	200	$	—
Provision for future cost of removal⁽¹⁰⁾		80		80
Other		25		47
Regulatory liabilities-current ⁽¹¹⁾		305		127
Income taxes refundable through future rates⁽¹²⁾		2,567		2,581
Nuclear decommissioning trust⁽¹³⁾		1,147		1,121
Provision for future cost of removal⁽¹⁰⁾		927		915
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁴⁾		72		—
Derivatives⁽⁸⁾		65		69

Other		99		74
Regulatory liabilities-noncurrent		4,877		4,760
Total regulatory liabilities	$	5,182	$	4,887
Dominion Energy Gas
Regulatory assets:
Deferred rate adjustment clause costs⁽²⁾	$	33	$	14
Unrecovered gas costs⁽⁴⁾		—		8
Other		2		4
Regulatory assets-current⁽¹⁵⁾		35		26
Unrecognized pension and other postretirement benefit costs⁽⁵⁾		251		258
Utility reform legislation⁽⁷⁾		174		147
Deferred rate adjustment clause costs⁽²⁾		76		89
Other		25		17
Regulatory assets-noncurrent⁽¹⁶⁾		526		511
Total regulatory assets	$	561	$	537
Regulatory liabilities:
Overrecovered gas costs⁽⁴⁾	$	18	$	—
Provision for future cost of removal and AROs⁽¹⁰⁾		13		13
PIPP⁽¹⁷⁾		3		20
Other		14		5
Regulatory liabilities-current⁽¹¹⁾		48		38
Income taxes refundable through future rates⁽¹²⁾		993		998
Provision for future cost of removal and AROs⁽¹⁰⁾		165		160
Cost-of-service impact of 2017 Tax Reform Act⁽¹⁴⁾		11		—
Other		84		69
Regulatory liabilities-noncurrent		1,253		1,227
Total regulatory liabilities	$	1,301	$	1,265

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

(2)

Primarily reflects deferrals under the 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. See Note 13 for more information.

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

(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's and Dominion Energy Gas' rate-regulated subsidiaries.

(6)	Reflects amounts related to the PJM transmission cost allocation matter. See Note 13 for more information.

(7)

Ohio legislation under House Bill 95, 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 approval 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.

(8)	For jurisdictions subject to cost-based rate regulation, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities as they are expected to be recovered from or refunded to customers.

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

(10)	Rates charged to customers by the Companies’ 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)	Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets.

(12) 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.

(13)

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.

(14)	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 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)	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 according to East Ohio tariff provisions.

At June 30, 2018, $427 million of Dominion Energy's and $349 million of Virginia Power's regulatory assets represented past expenditures on which they do not currently earn a return. With the exception of the $237 million PJM transmission cost allocation matter, 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 matters for which 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 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. 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 of 11.4%, 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 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. 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, 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 according to each customer’s share 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 proceeding regarding the cost allocation issue. The hearing only concerns the costs of new facilities approved by PJM prior to February 1, 2013. Transmission facilities approved after February 1, 2013 are allocated 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. As a result, Virginia Power will begin to make payments to PJM over the next 10 years under the terms of revised tariff records beginning in August 2018. Accordingly, at June 30, 2018, Virginia Power’s Consolidated Balance Sheet includes $148 million included in other current liabilities and $98 million included in other deferred credits and other liabilities, which are partially offset by a $237 million regulatory asset for the amount that will be recovered through retail rates in Virginia.

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 and Dominion Energy Gas’ results of operations. In December 2017, DETI provided its response to the audit report. DETI requested FERC review of contested findings and submitted its plan for compliance with 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 second 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. 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 to the enactment of the 2017 Tax Reform Act, the Companies’ state regulators issued orders requesting that public utilities evaluate the total tax impact on the entity’s cost of service and accrue a regulatory liability attributable to the benefits of the reduction 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.

In January 2018, the Virginia Commission issued an order directing Virginia utilities to reflect the impacts of the 2017 Tax Reform Act in the annual informational filings submitted to the Virginia Commission. Virginia Power submitted this filing in June 2018. Also, in

May and 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. The interim rate reduction totals approximately $125 million on an annual basis effective July 2018.

In February 2018, Virginia Power submitted a response to the North Carolina Utilities Commission detailing the impact of the 2017 Tax Reform Act on base non-fuel cost of service and Virginia Power’s excess deferred income taxes clarifying that the amounts have been deferred to a regulatory liability.

In May 2018, 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. The impact of excess deferred income taxes resulting from the 2017 Tax Reform Act on rates charged to customers will be reported to the Utah and Wyoming Commissions by the first quarter of 2019.

In March 2018, East Ohio submitted responses to the Ohio Commission’s request for comments on those components of utility rates that will need to be reconciled with the 2017 Tax Reform Act, and on the process and mechanics by which the Ohio Commission should do so. This matter is 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. This matter is pending.

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 require all interstate natural gas pipelines to make a one-time informational filing with FERC 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. Given these developments and associated uncertainty, Dominion Energy and Dominion Energy Gas are currently unable to predict the outcome of these matters; however, any change in rates permitted to be charged to customers could have a material impact on results of operations, financial condition and/or cash flows. Virginia Power’s regulated electric transmission formula rate mechanism includes provisions allowing changes in income tax rates to be incorporated in rates charged to customers.

Other Regulatory Matters

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

Virginia Regulation

Virginia Fuel Expenses

In May 2018, Virginia Power filed its annual fuel factor with the Virginia Commission to recover an estimated $1.5 billion in Virginia jurisdictional projected fuel expenses for the rate year beginning July 1, 2018. Virginia Power’s proposed fuel rate represented a fuel revenue increase of $222 million when applied to projected kilowatt-hour sales for the period July 1, 2018 to June 30, 2019. This matter is pending.

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 the first review, which will be a 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 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 a 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 projects and may not be included in base rates in future triennial review proceedings.

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 addition, Virginia Power will reduce base rates on an annual basis by $125 million effective July 2018, to reflect the estimated effect of the 2017 Tax Reform Act, which is subject to adjustment in April 2019.

In July 2018, Virginia Power filed a petition with the Virginia Commission for approval of the first three years of its ten-year plan for electric distribution grid transformation projects as authorized by the Grid Transformation and Security Act of 2018. During the first three years of the plan, Virginia Power proposes to focus on the following seven foundational components of the overall grid transformation plan: (i) smart meters; (ii) customer information platform; (iii) reliability and resilience; (iv) telecommunications infrastructure; (v) cyber and physical security; (vi) predictive analytics; and (vii) emerging technology. The total estimated capital investment during 2019-2021 is $816 million and the proposed operations and maintenance expenses are $102 million. This matter is pending.

Rate Adjustment Clauses

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

•

The Virginia Commission previously approved Rider T1 concerning transmission rates. In May 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, subject to true-up, for the rate year beginning September 1, 2018. This total revenue requirement represents a $146 million increase versus the revenues to be produced during the rate year under current rates. This matter is pending.

•

The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2018, Virginia Power proposed a $220 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $2 million increase over the previous year. This matter is pending.

•	The Virginia Commission previously approved Rider W in conjunction with Warren County. In June 2018, Virginia Power proposed a $107 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $2 million decrease over the previous year. This matter is pending.

•	The Virginia Commission previously approved Rider R in conjunction with Bear Garden. In June 2018, Virginia Power proposed a $59 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $7 million decrease over the previous year. This matter is pending.

•

The Virginia Commission previously approved Rider B in conjunction with the conversion of three power stations to biomass. In June 2018, Virginia Power proposed a $54 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $7 million increase over the previous year. This matter is pending.

•

The Virginia Commission previously approved Rider GV in conjunction with Greensville County. In June 2018, Virginia Power proposed a $121 million total revenue requirement for the rate year beginning April 1, 2019, which represents a $39 million increase over the previous year. This matter is pending.

•

The Virginia Commission previously approved Riders C1A and C2A in connection with cost recovery for DSM programs. In October 2017, Virginia Power requested approval to extend one existing energy efficiency program for five years with a new $25 million cost cap, and proposed a total $31 million revenue requirement for the rate year beginning July 1, 2018, which represents

a $3 million increase over the previous year. In May 2018, the Virginia Commission approved a total revenue requirement of $31 million, subject to true-up.

•

The Virginia Commission previously approved Rider BW in conjunction with Brunswick County. In October 2017, Virginia Power proposed a $132 million revenue requirement for the rate year beginning September 1, 2018, which represents a $5 million increase over the previous year. In July 2018, the Virginia Commission approved a $116 million revenue requirement, subject to true-up, for the rate year beginning September 1, 2018.

•

The Virginia Commission previously approved Rider US-2 in conjunction with Scott Solar, Whitehouse, and Woodland. In October 2017, Virginia Power proposed a $15 million revenue requirement for the rate year beginning September 1, 2018, which represents a $5 million increase over the previous year. In July 2018, the Virginia Commission approved a $13 million revenue requirement, subject to true-up, for the rate year beginning September 1, 2018.

Solar Facility Projects

In July 2018, Virginia Power filed an application with the Virginia Commission for CPCNs to construct two solar facilities. Colonial Trail West and Spring Grove 1 are estimated to cost approximately $410 million, excluding financing costs. Colonial Trail West and Spring Grove 1 are expected to commence commercial operations, subject to regulatory approvals associated with the projects, in the fourth quarter of 2019 and the fourth quarter of 2020, respectively. Virginia Power also applied for approval of Rider US-3 associated with these projects with a proposed $11 million total revenue requirement for the rate year beginning March 1, 2019. This matter is pending.

Electric Transmission Projects

In July 2017, the National Parks Conservation Association filed a lawsuit in U.S. District Court for the District of Columbia seeking to set aside the permit granted by the U.S. Army Corps of Engineers for the Surry-to-Skiffes Creek-to-Whealton electric transmission line project and requested a preliminary injunction against the permit. In August 2017, the National Trust for Historic Preservation and Preservation Virginia filed a similar lawsuit and request for preliminary injunction in U.S. District Court for the District of Columbia. In October 2017, the preliminary injunction requests were denied. In May 2018, the District Court granted summary judgment in favor of the U.S. Army Corps of Engineers and Virginia Power and dismissed both lawsuits. In June 2018, the National Parks Conservation Association and the National Trust for Historic Preservation and Preservation Virginia appealed that decision to the U.S. Court of Appeals for the D.C. Circuit. The appeal is pending. Also in June 2018, the National Parks Conservation Association filed requests with the U.S. District Court for the District of Columbia and the U.S. Court of Appeals for the D.C. Circuit for an injunction against the permit pending appeal. The U.S. District Court for the District of Columbia denied the injunction request in June 2018 and the U.S. Court of Appeals for the D.C. Circuit similarly denied the request in July 2018.

Virginia Power previously filed an application with the Virginia Commission for a CPCN to convert an existing transmission line to 230 kV in Prince William County, Virginia, and Loudoun County, Virginia, and to construct and operate a new approximately five mile overhead 230 kV double circuit transmission line between a tap point near the Gainesville substation and a new to-be-constructed Haymarket substation. In June 2017, the Virginia Commission issued a final order approving an alternative route for the project, and granted the necessary CPCN. In July 2017, the Virginia Commission retained jurisdiction over the case to evaluate two requests to reconsider its decisions. Also in July 2017, Virginia Power requested that the Virginia Commission stay the proceeding while Virginia Power discussed the proposed route with leaders of Prince William County. In December 2017, the Virginia Commission granted in part the two motions for reconsideration, retained jurisdiction for further proceedings in the case and stayed the effectiveness of its final order. In March 2018, Virginia Power and the two parties seeking reconsideration entered into a stipulated settlement filed with the Virginia Commission agreeing that the project should be placed into an underground pilot program created by the Grid Transformation and Security Act of 2018. In June 2018, the Virginia Commission issued an order finding that the project is still needed. In July 2018, Virginia Power filed a request with the Virginia Commission to allow the project to participate in the underground pilot program. Subsequently, in July 2018, the Virginia Commission issued a final order granting the CPCN for the project and allowing the project to participate in the underground pilot program.

In May 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in Chesterfield County and the City of Hopewell, Virginia approximately 8 miles of 230 kV transmission line between the Chesterfield and Hopewell substations, along with associated substation work. The total estimated cost of the project is approximately $30 million. This matter is pending.

In May 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in Chesterfield and Henrico Counties, Virginia approximately 21 miles of 230 kV transmission line between the Chesterfield and Lakeside substations, along with associated substation work. The total estimated cost of the project is approximately $35 million. This matter is pending.

In June 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in the Cities of Virginia Beach and Chesapeake, Virginia approximately 8.5 miles of 230 kV transmission line between the Landstown and Thrasher substations, along with associated substation work. The total estimated cost of the project is approximately $20 million. This matter is pending.

In June 2018, Virginia Power filed an application with the Virginia Commission for a CPCN to rebuild and operate in King and Queen, King William, and New Kent Counties, Virginia four separate segments of 230 kV transmission line between Lanexa and the Northern Neck in Virginia. The total estimated cost of the project is approximately $35 million. This matter is pending.

Ohio Regulation

PIPP Plus Program

Under the Ohio PIPP Plus Program, eligible customers can make reduced payments based on their ability to pay their bill. The difference between the customer’s total bill and the PIPP amount is deferred and collected under the PIPP Rider in accordance with the rules of the Ohio Commission. In May 2018, East Ohio filed its annual update of the PIPP Rider with the Ohio Commission. The revised rider rate reflects recovery over the twelve-month period from July 2018 through June 2019 of projected deferred program costs of approximately $10 million from April 2018 through June 2019, net of a refund for over-recovery of accumulated arrearages of approximately $4 million as of March 31, 2018. This matter is pending.

UEX Rider

East Ohio has approval for a UEX Rider through which it recovers the bad debt expense of most customers not participating in the PIPP Plus Program. The UEX Rider is adjusted annually to achieve dollar for dollar recovery of East Ohio’s actual write-offs of uncollectible amounts. In May 2018, East Ohio filed an application with the Ohio Commission requesting approval of its UEX Rider to reflect a refund of over-recovered accumulated bad debt expense of approximately $11 million as of March 31, 2018, and recovery of prospective net bad debt expense projected to total approximately $16 million for the twelve-month period from April 2018 to March 2019. This matter is pending.

Utah and Wyoming Regulation

In the second quarter of 2018, Questar Gas filed a request with the Utah Commission 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 to receive a prudency determination from the Utah Commission before making a capital investment in the facility. Under the pre-approval statute, the Utah Commission has 180 days to make a prudency determination. Based on this timeline, a determination is expected by the end of October 2018.

In May 2018, Questar Gas submitted filings with both the Utah Commission and Wyoming Commission for an approximately $86 million gas cost decrease reflecting forecasted decreases in commodity costs. The Utah Commission and the Wyoming Commission both approved the filings in May 2018 with rates effective June 2018.

West Virginia Regulation

In May 2018, Hope filed a PREP application with the Public Service Commission of West Virginia requesting approval to recover PREP costs related to $31 million and $36 million of projected capital investment for 2018 and 2019, respectively. The application also includes a true-up of PREP costs related to the 2017 actual capital investment of $28 million and sets forth $8 million of annual PREP costs to be recovered in proposed rates effective November 1, 2018. This matter is pending.

Note 14. 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

Dominion Energy’s securities due within one year and long-term debt include $29 million and $324 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 long-term power and capacity contracts with three non-utility generators. Contracts with two of these non-utility generators expired in the third quarter 2017 leaving a remaining 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 $175 million as of June 30, 2018. Virginia Power paid $12 million and $28 million for electric capacity and $5 million and $7 million for electric energy to non-utility generators in the three months ended June 30, 2018 and 2017, respectively. Virginia Power paid $25 million and $56 million for electric capacity and $10 million and $15 million for electric energy to non-utility generators in the six months ended June 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 $83 million and $31 million for the three months ended June 30, 2018, $83 million and $31 million for the three months ended June 30, 2017, $172 million and $63 million for the six months ended June 30, 2018 and $168 million and $62 million for the six months ended June 30, 2017, respectively. Virginia Power and Dominion Energy Gas’ Consolidated Balance Sheets included amounts due to DES of $35 million and $12 million, respectively, at June 30, 2018, and $36 million and $14 million, respectively, at December 31, 2017, recorded in payables to affiliates in the Consolidated Balance Sheets.

Note 15. Significant Financing Transactions

Credit Facilities and Short-term Debt

The Companies use short-term debt to fund working capital requirements and as a bridge to long-term debt financings. The levels of borrowing may vary significantly during the course of the year, depending upon the timing and amount of cash requirements not satisfied by cash from operations. In addition, Dominion Energy utilizes cash and letters of credit to fund collateral requirements. Collateral requirements are impacted by commodity prices, hedging levels, Dominion Energy’s credit ratings and the credit quality of its counterparties.

Dominion Energy

In March 2018, Dominion Energy replaced its two existing joint revolving credit facilities with a $6.0 billion joint revolving credit facility. At June 30, 2018, 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

(millions)

Joint revolving credit facility⁽¹⁾

6,000

2,743

3,185

(1)	This credit facility matures in March 2023 and can be used by the Companies 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 as co-borrower to the joint revolving credit facility discussed above with Dominion Energy, Virginia Power and Dominion Energy Gas. At June 30, 2018, the sub-limit for Questar Gas was $250 million.

In addition to the credit facility 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 June 30, 2018, no amounts were outstanding under either of these facilities.

In February 2018, Dominion Energy borrowed $950 million under a 364-Day Term Loan Agreement that bears interest at a variable rate. In addition, the agreement contains a maximum allowed total debt to total capital ratio of 67.5%.

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

In June 2018, Dominion Energy borrowed $500 million under a 364-Day Term Loan Agreement that bears interest at a variable rate. In addition, the agreement contains a maximum allowed total debt to total capital ratio of 67.5%.

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 and for other general corporate purposes.

At June 30, 2018, 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 was as follows:

Facility

Limit⁽¹⁾

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

(millions)

Joint revolving credit facility⁽¹⁾

6,000

1,158

(1)

The full amount of the facility is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion Energy, Dominion Energy Gas and Questar Gas. The sub-limit for Virginia Power is set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2018, 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 and for other general corporate purposes.

At June 30, 2018, 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 was as follows:

Facility

Limit⁽¹⁾

Outstanding

Commercial

Paper

Outstanding

Letters of

Credit

(millions)

Joint revolving credit facility⁽¹⁾

1,500

188

—

(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 and Questar Gas. The sub-limit for Dominion Energy Gas is set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2018, 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, Dominion Energy Questar Pipeline issued, through private placement, $100 million of 3.53% senior notes and $150 million of 3.91% senior notes that mature in 2028 and 2038, respectively. The proceeds were used to repay maturing long-term debt.

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, Dominion Energy issued through private placement $500 million of variable rate senior notes that mature in 2020.

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

In June 2018, Dominion Energy Gas issued $500 million of variable rate senior notes that mature in 2021.

Noncontrolling Interest in Dominion Energy Midstream

In May 2018, all of the subordinated units of Dominion Energy Midstream held by Dominion Energy were converted into common units on a 1:1 ratio following the payment of Dominion Energy Midstream’s distribution for the first quarter of 2018. In June 2018, Dominion Energy, as general partner, exercised an incentive distribution right reset as defined in Dominion Energy Midstream’s partnership agreement and received 27 million common units representing limited partner interests in Dominion Energy Midstream. As a result of the increase in its ownership interest in Dominion Energy Midstream, Dominion Energy recorded a decrease in noncontrolling interest, and a corresponding increase in shareholders’ equity, of $375 million reflecting the change in the carrying value of the interest in the net assets of Dominion Energy Midstream held by others.

Issuance of Common Stock

At-the-Market Programs

In June 2017, Dominion Energy filed an SEC shelf registration statement for the sale of debt and equity securities including the ability to sell common stock through an at-the-market program. 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 to offer up to $500 million aggregate amount of its common stock. In January 2018, Dominion Energy provided sales instructions to one of the sales agents and issued 6.6 million shares through at-the-market issuances and received cash proceeds of $495 million, net of fees and commissions paid of $5 million. Following these issuances, Dominion Energy had no remaining ability to issue stock under the 2017 sales agency agreements and completed the 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 and none are planned 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. 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 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 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. Beginning in August 2017, PJM filed requests for 90-day renewals of the DOE order, which the DOE has granted. The current renewal is effective until September 2018. The Sierra Club has challenged the DOE order and certain renewal requests, all of which have been denied by the DOE.

Although litigation of the MATS rule is 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. This application is pending. Due to the uncertainty surrounding a final plan for compliance with this ozone standard, Dominion Energy and 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.

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, 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. 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 financial statements.

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 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 their results of operations, financial condition and/or cash flows.

Water

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

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 have 13 and 11 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 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 and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory framework in Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts for Virginia Power.

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 and Virginia Power’s results of operations, financial condition and/or cash flows, the existing regulatory framework in Virginia provides rate recovery mechanisms that could substantially mitigate any such impacts for Virginia Power.

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 19 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 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 late 2018. 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. 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

Pipeline Contractor Litigation

Following the completion of the Appalachian Gateway project in 2012, DETI received multiple change order requests and other claims for additional payments from a pipeline contractor for the project. In July 2015, the contractor filed a complaint against DETI in U.S. District Court for the Western District of Pennsylvania. In March 2016, the Pennsylvania court granted DETI’s motion to transfer the case to the U.S. District Court for the Eastern District of Virginia. In July 2016, DETI filed a motion to dismiss. In March 2017, the court dismissed three of eight counts in the complaint. In May 2017, the contractor withdrew one of the counts in the complaint. In November 2017, DETI and the contractor entered into a partial settlement agreement for a release of certain claims. This case is pending. At June 30, 2018, DETI has accrued a liability of $14 million for this matter, recorded in other current liabilities in the Consolidated Balance Sheets. Dominion Energy Gas cannot currently estimate additional financial statement impacts, but there could be a material impact to its financial condition and/or cash flows.

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 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 claims are pending in the Business Court Division of West Virginia. Dominion Energy and Dominion Energy Gas cannot currently estimate financial statement impacts, but there could be a material impact to their 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. This case is pending.

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 currently operates inactive ash ponds, existing ash ponds, and CCR landfills subject to the final rule at eight different facilities. This rule created a legal obligation for Virginia Power to retrofit or close all of its inactive and existing ash ponds over a certain period of time, as well as perform required monitoring, corrective action, and post-closure care activities as necessary.

In December 2016, legislation was enacted that creates a framework for EPA-approved state CCR permit programs. In August 2017, the EPA issued interim guidance outlining the framework for state CCR program approval. The EPA has enforcement authority until state programs are approved. The EPA and states with approved programs both will have authority to enforce CCR requirements under their respective rules and programs. In September 2017, the EPA agreed to reconsider portions of the CCR rule in response to two petitions for reconsideration. Litigation concerning the CCR rule is pending and the EPA has submitted to the court a list of which CCR rule provisions the EPA intends to reevaluate. 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, 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 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 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 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 extended moratorium does not apply to a permit required for an impoundment where CCRs have already been removed and placed in another impoundment on-site, are being removed from an impoundment, or are being processed in connection with a recycling or beneficial use project. In connection with this legislation, Virginia Power recorded an increase to its ARO and a related environmental liability related to future ash pond and landfill closure costs of $131 million, which resulted in an $81 million ($60 million after-tax) charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $46 million increase in property, plant and equipment associated with asset retirement costs and a $4 million increase in regulatory assets. The actual AROs related to the CCR rule 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. This case is pending.

FERC

FERC staff in the Office of Enforcement, Division of Investigations, is conducting 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. Virginia Power is cooperating fully with the investigation; however, it cannot currently predict whether or to what extent it may incur a material 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 external flooding hazards is expected to continue through 2018. 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 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

Dominion Energy and Virginia Power 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. 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 June 30, 2018, Atlantic Coast Pipeline has borrowed $877 million against the revolving credit facility. Dominion Energy’s Consolidated Balance Sheets include a liability of $30 million associated with this guarantee agreement at June 30, 2018.

In addition, at June 30, 2018, Dominion Energy had issued $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 June 30, 2018, Dominion Energy had issued the following subsidiary guarantees:

	Maximum Exposure
(millions)
Commodity transactions⁽¹⁾	$	2,142
Nuclear obligations⁽²⁾		200
Cove Point⁽³⁾		1,900
Solar⁽⁴⁾		636
Other⁽⁵⁾		577
Total⁽⁶⁾	$	5,455

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

(2)	Guarantees 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 June 30, 2018, Dominion Energy's maximum remaining cumulative exposure under these equity funding agreements is $10 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $6 million.

(6)

Excludes Dominion Energy's guarantee for the construction of a 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, as updated in Current Report on Form 8-K, filed June 6, 2018.

Additionally, at June 30, 2018, Dominion Energy had purchased $165 million of surety bonds, including $70 million at Virginia Power and $24 million at Dominion Energy Gas, and authorized the issuance of letters of credit by financial institutions of $72 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. 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 June 30, 2018, Dominion Energy’s gross credit exposure related to energy marketing and price risk management activities totaled $67 million. Of this amount, investment grade counterparties, including those internally rated, represented 30%. No single counterparty, whether investment grade or non-investment grade, exceeded $7 million of exposure. At June 30, 2018, Virginia Power’s exposure related to wholesale customers totaled $52 million. Of this amount, investment grade counterparties, including those internally rated, represented 24%. No single counterparty, whether investment grade or non-investment grade, exceeded $9 million of exposure. At June 30, 2018, Dominion Energy Gas’ exposure primarily related to wholesale customers totaled less than $1 million. Of this amount, investment grade counterparties, including those internally rated, represented 82%. 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 June 30, 2018 and December 31, 2017, Dominion Energy would have been required to post $11 million and $62 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 June 30, 2018 or December 31, 2017 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 at June 30, 2018 and December 31, 2017 was $13 million and $65 million, respectively, 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 as of June 30, 2018 and December 31, 2017. See Note 9 for further information about derivative instruments.

Note 18. 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 commodity swaps, to manage commodity price risks associated with purchases of natural gas. At June 30, 2018, Virginia Power’s derivative assets and liabilities with affiliates were $9 million and $5 million, respectively. At December 31, 2017, Virginia Power’s derivative assets and liabilities with affiliates were $11 million and $5 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 June 30, 2018 and December 31, 2017, 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 $569 million and $505 million, respectively. At June 30, 2018 and December 31, 2017, 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 $236 million and $199 million, respectively.

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

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
(millions)
Commodity purchases from affiliates	$	139	$	137	$	537	$	349
Services provided by affiliates⁽¹⁾		112		112		232		224
Services provided to affiliates		5		7		11		12

(1)	Includes capitalized expenditures of $38 million and $37 million for the three months ended June 30, 2018 and 2017, respectively, and $75 million and $71 million for the six months ended June 30, 2018 and 2017, respectively.

Virginia Power has borrowed funds from Dominion Energy under short-term borrowing arrangements. There were $25 million and $33 million in short-term demand note borrowings from Dominion Energy as of June 30, 2018 and December 31, 2017, respectively. Virginia Power had no outstanding borrowings, net of repayments, under the Dominion Energy money pool for its nonregulated

subsidiaries as of June 30, 2018 and December 31, 2017. Interest charges related to Virginia Power’s borrowings from Dominion Energy were less than $1 million for the three and six months ended June 30, 2018 and 2017.

There were no issuances of Virginia Power’s common stock to Dominion Energy for the three and six months ended June 30, 2018 and 2017.

Dominion Energy Gas

Transactions with Related Parties

Dominion Energy Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Energy Gas provides transportation and storage services to affiliates. Dominion Energy Gas also enters into certain other contracts with affiliates and related parties, including construction services, which are presented separately from contracts involving commodities or services. As of June 30, 2018, Dominion Energy Gas had no derivative assets and $7 million of derivative liabilities with affiliates. As of December 31, 2017, 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 June 30, 2018 and December 31, 2017, 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 $753 million and $734 million, respectively. At June 30, 2018 and December 31, 2017, 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 $10 million and $7 million, respectively.

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 June 30,					Six Months Ended June 30,
	2018			2017		2018		2017
(millions)
Sales of natural gas and transportation and storage services to affiliates	$	16		$	18	$	34	$	36
Purchases of natural gas from affiliates		(2	)		1		1		—
Services provided by related parties⁽¹⁾		33			36		66		73
Services provided to related parties⁽²⁾		61			36		113		75

(1)	Includes capitalized expenditures of $7 million and $12 million for the three months ended June 30, 2018 and 2017, respectively, and $17 million and $20 million for the six months ended June 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:

	June 30, 2018		December 31, 2017
(millions)
Other receivables⁽¹⁾	$	19	$	12
Customer receivables from related parties		—		1
Imbalances receivable from affiliates		—		1
Imbalances payable to affiliates⁽²⁾		5		—
Affiliated notes receivable⁽³⁾		18		20

(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 $56 million and $18 million as of June 30, 2018 and December 31, 2017, respectively. Interest charges related to Dominion Energy Gas’ total borrowings from Dominion Energy were immaterial for the three and six months ended June 30, 2018 and 2017.

Note 19. 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
	2018			2017			2018			2017
(millions)
Three Months Ended June 30,
Service cost	$	40		$	34		$	6		$	6
Interest cost		84			87			14			14
Expected return on plan assets		(168	)		(161	)		(35	)		(31	)
Amortization of prior service cost (credit)		1			1			(13	)		(13	)
Amortization of net actuarial loss		49			41			2			3
Net periodic benefit cost (credit)	$	6		$	2		$	(26	)	$	(21	)
Six Months Ended June 30,
Service cost	$	79		$	69		$	13		$	13
Interest cost		168			173			28			30
Expected return on plan assets		(333	)		(320	)		(71	)		(63	)
Amortization of prior service cost (credit)		1			1			(26	)		(25	)
Amortization of net actuarial loss		97			81			5			6
Settlements		—			1			—			—
Net periodic benefit cost (credit)	$	12		$	5		$	(51	)	$	(39	)

Employer Contributions

During the six months ended June 30, 2018, Dominion Energy made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion Energy expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs during the remainder of 2018.

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:

	Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017
(millions)
Three Months Ended June 30,
Service cost	$	5		$	4		$	1		$	1
Interest cost		7			8			2			3
Expected return on plan assets		(38	)		(36	)		(6	)		(6	)
Amortization of prior service credit		—			—			(1	)		(1	)
Amortization of net actuarial loss		5			4			1			—
Net periodic benefit credit	$	(21	)	$	(20	)	$	(3	)	$	(3	)
Six Months Ended June 30,
Service cost	$	9		$	8		$	2		$	2
Interest cost		14			15			5			6
Expected return on plan assets		(75	)		(71	)		(14	)		(12	)
Amortization of prior service credit		—			—			(2	)		(1	)
Amortization of net actuarial loss		10			8			2			1
Net periodic benefit credit	$	(42	)	$	(40	)	$	(7	)	$	(4	)

Employer Contributions

During the six months ended June 30, 2018, 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.

Note 20. Operating Segments

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

Primary Operating Segment	Description of Operations	Dominion Energy	Virginia Power	Dominion Energy Gas
Power Delivery	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
Power Generation	Regulated electric fleet	X	X
	Merchant electric 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

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 six months ended June 30, 2018, Dominion Energy reported after-tax net expenses of $349 million for specific items in the Corporate and Other segment, with $310 million of net expenses attributable to its operating segments. In the six months ended June 30, 2017, Dominion Energy reported after-tax net expenses of $10 million for specific items in the Corporate and Other segment, with $1 million of net expenses attributable to its operating segments.

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 $122 million ($89 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
(millions)
Three Months Ended June 30, 2018
Total revenue from external customers	$	528	$	1,635	$	914	$	(3	)	$	14		$	3,088
Intersegment revenue		6		3		8		170			(187	)		—
Total operating revenue		534		1,638		922		167			(173	)		3,088
Net income (loss) attributable to Dominion Energy		145		276		249		(221	)		—			449
Three Months Ended June 30, 2017
Total revenue from external customers	$	530	$	1,507	$	589	$	6		$	181		$	2,813
Intersegment revenue		7		2		175		149			(333	)		—
Total operating revenue		537		1,509		764		155			(152	)		2,813
Net income (loss) attributable to Dominion Energy		127		240		163		(140	)		—			390
Six Months Ended June 30, 2018
Total revenue from external customers	$	1,091	$	3,495	$	2,136	$	(210	)	$	42		$	6,554
Intersegment revenue		12		5		14		345			(376	)		—
Total operating revenue		1,103		3,500		2,150		135			(334	)		6,554
Net income (loss) attributable to Dominion Energy		301		624		576		(549	)		—			952
Six Months Ended June 30, 2017
Total revenue from external customers	$	1,084	$	3,160	$	1,490	$	9		$	454		$	6,197
Intersegment revenue		12		5		441		301			(759	)		—
Total operating revenue		1,096		3,165		1,931		310			(305	)		6,197
Net income (loss) attributable to Dominion Energy		252		501		426		(157	)		—			1,022

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 six months ended June 30, 2018, Virginia Power reported after-tax net expenses of $237 million for specific items in the Corporate and Other segment, with $230 million of net expenses attributable to its operating segments. In the six months ended June 30, 2017, Virginia Power reported after-tax net expenses of $7 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments.

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 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 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.

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 June 30, 2018
Operating revenue	$	528	$	1,301	$	—		$	1,829
Net income (loss)		145		227		(33	)		339
Three Months Ended June 30, 2017
Operating revenue	$	533	$	1,214	$	—		$	1,747
Net income (loss)		125		198		(5	)		318
Six Months Ended June 30, 2018
Operating revenue	$	1,091	$	2,701	$	(215	)	$	3,577
Net income (loss)		299		449		(225	)		523
Six Months Ended June 30, 2017
Operating revenue	$	1,090	$	2,488	$	—		$	3,578
Net income		250		421		3			674

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 the six months ended June 30, 2018, Dominion Energy Gas reported after-tax net expenses of $91 million for specific items in the Corporate and Other segment, with $89 million of net expenses attributable to its operating segment. In the six months ended June 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 $122 million ($89 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 at June 30, 2017.

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

	Gas Infrastructure		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2018
Operating revenue	$	459	$	—		$	459
Net income (loss)		108		(93	)		15
Three Months Ended June 30, 2017
Operating revenue	$	422	$	—		$	422
Net income (loss)		88		(11	)		77
Six Months Ended June 30, 2018
Operating revenue	$	985	$	—		$	985
Net income (loss)		275		(94	)		181
Six Months Ended June 30, 2017
Operating revenue	$	912	$	—		$	912
Net income (loss)		197		(12	)		185

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;

•	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;

•	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, 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;

•	The timing and execution of Dominion Energy Midstream’s growth strategy;

•	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 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 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;

•	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.

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

Accounting Matters

Critical Accounting Policies and Estimates

As of June 30, 2018, 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)
Second Quarter
Net income attributable to Dominion Energy	$	449	$	390	$	59
Diluted EPS		0.69		0.62		0.07
Year-to-Date
Net income attributable to Dominion Energy	$	952	$	1,022	$	(70	)
Diluted EPS		1.46		1.63		(0.17	)

Overview

Second Quarter 2018 vs. 2017

Net income attributable to Dominion Energy increased 15%, primarily due to the commencement of commercial operations of the Liquefaction Project, increased net investment earnings on nuclear decommissioning trust funds, fewer planned outage days at certain merchant and utility generation facilities and the retroactive application of depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements. These increases were partially offset by a charge for disallowance of FERC-regulated plant and a charge associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018.

Year-To-Date 2018 vs. 2017

Net income attributable to Dominion Energy decreased 7%, primarily due to a charge associated with Virginia legislation enacted in March 2018, a charge for disallowance of FERC-regulated plant and a charge associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018. These decreases were partially offset by an

increase in heating and cooling degree days in the electric utility service territory, favorable pricing at merchant generation facilities and the commencement of commercial operations of the Liquefaction Project.

Analysis of Consolidated Operations

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

	Second Quarter								Year-To-Date
	2018		2017			$ Change			2018		2017			$ Change
(millions)
Operating revenue	$	3,088	$	2,813		$	275		$	6,554	$	6,197		$	357
Electric fuel and other energy-related purchases		623		498			125			1,367		1,073			294
Purchased (excess) electric capacity		23		(12	)		35			37		(29	)		66
Purchased gas		64		112			(48	)		404		417			(13	)
Net revenue		2,378		2,215			163			4,746		4,736			10
Other operations and maintenance		1,007		827			180			1,803		1,611			192
Depreciation, depletion and amortization		463		467			(4	)		961		936			25
Other taxes		166		168			(2	)		365		357			8
Other income		185		108			77			285		270			15
Interest and related charges		361		308			53			675		600			75
Income tax expense		88		136			(48	)		223		411			(188	)
Noncontrolling interests		29		27			2			52		69			(17	)

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

Second Quarter 2018 vs. 2017

Net revenue increased 7%, primarily reflecting:

•

A $143 million increase due to commencement of commercial operations of the Liquefaction Project, including terminalling services provided to the export customers ($159 million) and regulated gas transportation contracts to serve the export customers ($19 million), partially offset by credits associated with the start-up phase of the Liquefaction Project ($35 million);

•	A $35 million increase due to growth projects placed in service, other than the Liquefaction Project;

•	A $33 million increase in sales to electric utility retail customers from an increase in cooling degree days;

•	A $31 million increase from certain merchant generation facilities due to fewer planned outage days and favorable pricing;

•	A $30 million increase in services performed for Atlantic Coast Pipeline; and

•	A $21 million increase in sales to electric utility retail customers due to the effect of changes in customer usage and other factors ($8 million) and customer growth ($13 million); partially offset by

•	A $70 million decrease for regulated electric generation and electric and gas distribution operations as a result of the 2017 Tax Reform Act;

•	A $39 million decrease in rate adjustment clauses associated with electric utility operations; and

•

A $37 million increase in net electric capacity expense related to the annual PJM capacity performance market effective June 2017 ($45 million) and the annual PJM capacity performance market effective June 2018 ($6 million), partially offset by a benefit related to non-utility generators ($14 million).

Other operations and maintenance increased 22%, primarily reflecting:

•	A $134 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; and

•	A $28 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 $59 million decrease from a reduction in planned outage days at certain merchant and utility generation facilities.

Depreciation, depletion and amortization was consistent period over period as decreases from the retroactive application of depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements ($46 million) and various other individually insignificant items ($17 million) were offset by increases from various growth projects being placed into service ($59 million), including the Liquefaction Project ($23 million).

Other income increased 71%, primarily reflecting an increase in net investment earnings on nuclear decommissioning trust funds ($48 million), an increase in earnings from equity method investments ($22 million) and the absence of a charge associated with a customer settlement ($16 million).

Interest and related charges increased 17%, primarily due to the absence of capitalization of interest expense associated with the Liquefaction Project upon completion of construction ($33 million), higher long-term debt interest expense resulting from debt issuances in the first and second quarter of 2018 ($10 million) and increases in the carrying amount of commercial paper and associated interest rates ($7 million).

Income tax expense decreased 35%, primarily due to the 2017 Tax Reform Act ($94 million) and state legislative change ($18 million), partially offset by lower renewable energy investment tax credits ($37 million).

Year-To-Date 2018 vs. 2017

Net revenue increased $10 million, primarily reflecting:

•

•	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 ($33 million);

•	A $93 million increase due to favorable pricing at merchant generation facilities;

•	A $64 million increase due to growth projects placed in service, other than the Liquefaction Project;

•	A $45 million increase in services performed for Atlantic Coast Pipeline; and

•	A $20 million increase due to fewer planned outage days at certain merchant generation facilities; 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 $135 million decrease for regulated electric generation and electric and gas distribution operations as a result of the 2017 Tax Reform Act;

•

A $66 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 ($6 million), partially offset by a benefit related to non-utility generators ($52 million); and

•	A $42 million decrease in rate adjustment clauses associated with electric utility operations.

Other operations and maintenance increased 12%, primarily reflecting:

•	A $134 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 $44 million increase in services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income; and

•	A $35 million increase in storm damage and service restoration costs; partially offset by

•	A $66 million decrease from a reduction in planned outage days at certain merchant and utility generation facilities; and

•	A $50 million decrease from gains related to agreements to convey shale development rights under natural gas storage fields.

Depreciation, depletion and amortization increased 3%, primarily due to an increase from various growth projects being placed into service ($88 million), including the Liquefaction Project ($23 million), partially offset by the retroactive application of depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements ($46 million).

Interest and related charges increased 13%, primarily due to the absence of capitalization of interest expense associated with the Liquefaction Project upon completion of construction ($33 million), higher long-term debt interest expense resulting from debt issuances in the first and second quarter of 2018 ($26 million) and increases in the carrying amount of commercial paper and associated interest rates ($14 million).

Income tax expense decreased 46%, primarily due to the 2017 Tax Reform Act ($170 million) and lower pre-tax income ($96 million), partially offset by lower renewable energy investment tax credits ($73 million).

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
	2018			2017			$ Change			2018			2017			$ Change
(millions, except EPS)
Second Quarter
Power Delivery	$	145		$	127		$	18		$	0.23		$	0.20		$	0.03
Power Generation		276			240			36			0.42			0.38			0.04
Gas Infrastructure		249			163			86			0.38			0.26			0.12
Primary operating segments		670			530			140			1.03			0.84			0.19
Corporate and Other		(221	)		(140	)		(81	)		(0.34	)		(0.22	)		(0.12	)
Consolidated	$	449		$	390		$	59		$	0.69		$	0.62		$	0.07

Year-To-Date
Power Delivery	$	301		$	252		$	49		$	0.46		$	0.40		$	0.06
Power Generation		624			501			123			0.96			0.80			0.16
Gas Infrastructure		576			426			150			0.88			0.68			0.20
Primary operating segments		1,501			1,179			322			2.30			1.88			0.42
Corporate and Other		(549	)		(157	)		(392	)		(0.84	)		(0.25	)		(0.59	)
Consolidated	$	952		$	1,022		$	(70	)	$	1.46		$	1.63		$	(0.17	)

Power Delivery

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

	Second Quarter							Year-To-Date
	2018		2017		% Change			2018		2017		% Change
Electricity delivered (million MWh)		20.9		19.7		6	%		43.0		40.2		7	%
Degree days (electric distribution service area):
Cooling		611		565		8			619		574		8
Heating		284		186		53			2,306		1,823		26
Average electric distribution customer accounts (thousands)⁽¹⁾		2,597		2,570		1			2,594		2,567		1

(1)	Period average.

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

	Second Quarter 2018 vs. 2017 Increase (Decrease)					Year-To-Date 2018 vs. 2017 Increase (Decrease)
	Amount			EPS		Amount		EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	8		$	0.01	$	22	$	0.03
Other		12			0.02		16		0.02
FERC transmission equity return		1			—		5		0.01
Other		(3	)		—		6		0.01
Share dilution		—			—		—		(0.01	)
Change in net income contribution	$	18		$	0.03	$	49	$	0.06

Power Generation

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

	Second Quarter							Year-To-Date
	2018		2017		% Change			2018		2017		% Change
Electricity supplied (million MWh):
Utility		20.8		19.9		5	%		43.1		41.6		4	%
Merchant		7.7		7.3		5			15.0		14.8		1
Degree days (electric utility service area):
Cooling		611		565		8			619		574		8
Heating		284		186		53			2,306		1,823		26

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

	Second Quarter 2018 vs. 2017 Increase (Decrease)						Year-To-Date 2018 vs. 2017 Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
Merchant generation margin	33			0.06			$	94		$	0.15
Regulated electric sales:
Weather	13			0.02			41			0.06
Other		2			—			(7	)		(0.01	)
Electric capacity		(20	)		(0.03	)		(38	)		(0.06	)
Planned outage costs		36			0.06			40			0.06
Depreciation and amortization		10			0.02			10			0.02
Renewable energy investment tax credits		(55	)		(0.09	)		(55	)		(0.09	)
2017 Tax Reform Act impacts		9			0.01			32			0.05
Other		8			0.01			6			0.01
Share dilution		—			(0.02	)		—			(0.03	)
Change in net income contribution	$	36		$	0.04		$	123		$	0.16

100

Gas Infrastructure

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

	Second Quarter							Year-To-Date
	2018		2017		% Change			2018		2017		% Change
Gas distribution throughput (bcf):
Sales		19		18		6	%		76		75	1%
Transportation		158		139		14			372		326		14
Heating degree days (gas distribution service area):
Eastern region		670		481		39			3,585		2,874		25
Western region		405		576		(30	)		2,500		2,893		(14	)
Average gas distribution customer accounts (thousands)⁽¹⁾:
Sales		1,250		1,228		2			1,254		1,234		2
Transportation		1,105		1,099		1			1,100		1,093		1
Average retail energy marketing customer accounts (thousands)⁽¹⁾		862		1,451		(41	)		862		1,440		(40	)

(1)Period average.

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

	Second Quarter 2018 vs. 2017 Increase (Decrease)						Year-To-Date 2018 vs. 2017 Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
2017 Tax Reform Act impacts	$	28		$	0.04		$	60		$	0.09
Assignment of shale development rights		4			0.01			36			0.06
State legislative change		18			0.03			18			0.03
Transportation and storage growth projects		10			0.02			18			0.03
Cove Point export contracts		70			0.11			70			0.11
Cove Point import contracts		(2	)		—			(12	)		(0.02	)
Scheduled DETI contract declines		(3	)		(0.01	)		(6	)		(0.01	)
Interest expense, net		(27	)		(0.04	)		(28	)		(0.05	)
Other		(12	)		(0.02	)		(6	)		(0.01	)
Share dilution		—			(0.02	)		—			(0.03	)
Change in net income contribution	$	86		$	0.12		$	150		$	0.20

Corporate and Other

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

	Second Quarter									Year-To-Date
	2018			2017			$ Change			2018			2017			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	(92	)	$	(22	)	$	(70	)	$	(310	)	$	(1	)	$	(309	)
Specific items attributable to Corporate and Other segment		(19	)		(9	)		(10	)		(39	)		(9	)		(30	)
Total specific items		(111	)		(31	)		(80	)		(349	)		(10	)		(339	)
Other corporate operations:
Renewable energy investment tax credits		8			(12	)		20			12			27			(15	)
2017 Tax Reform Act impacts		(20	)		—			(20	)		(39	)		—			(39	)
Interest expense, net		(89	)		(88	)		(1	)		(172	)		(173	)		1
Other		(9	)		(9	)		—			(1	)		(1	)		—
Total other corporate operations		(110	)		(109	)		(1	)		(200	)		(147	)		(53	)
Total net expense	$	(221	)	$	(140	)	$	(81	)	$	(549	)	$	(157	)	$	(392	)
EPS impact	$	(0.34	)	$	(0.22	)	$	(0.12	)	$	(0.84	)	$	(0.25	)	$	(0.59	)

101

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 20 to the Consolidated Financial Statements in this report for discussion of these items in more detail. Corporate and Other also includes items attributable to the Corporate and Other segment.

Virginia Power

Results of Operations

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

	Second Quarter						Year-To-Date
	2018		2017		$ Change		2018		2017		$ Change
(millions)
Net income	$	339	$	318	$	21	$	523	$	674	$	(151	)

Overview

Second Quarter 2018 vs. 2017

Net income increased 7%, primarily due to the retroactive application of depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements, an increase in cooling degree days in the service territory and an increase in sales to retail customers due to the effect of changes in customer usage and other factors, partially offset by a charge associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018.

Year-To-Date 2018 vs. 2017

Net income decreased 22%, primarily due to a charge associated with Virginia legislation enacted in March 2018 and a charge associated primarily with future ash pond and landfill closure costs in connection with the enactment of Virginia legislation in April 2018, partially offset by an increase in heating and cooling degree days in the service territory.

Analysis of Consolidated Operations

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

	Second Quarter								Year-To-Date
	2018		2017			$ Change			2018		2017			$ Change
(millions)
Operating revenue	$	1,829	$	1,747		$	82		$	3,577	$	3,578		$	(1	)
Electric fuel and other energy-related purchases		508		409			99			1,099		865			234
Purchased (excess) electric capacity		23		(12	)		35			37		(29	)		66
Net revenue		1,298		1,350			(52	)		2,441		2,742			(301	)
Other operations and maintenance		439		379			60			838		753			85
Depreciation and amortization		247		280			(33	)		544		566			(22	)
Other taxes		79		78			1			162		157			5
Other income		21		13			8			24		44			(20	)
Interest and related charges		126		125			1			258		245			13
Income tax expense		89		183			(94	)		140		391			(251	)

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

Second Quarter 2018 vs. 2017

Net revenue decreased 4%, primarily reflecting:

•	A $45 million decrease for regulated generation and distribution operations as a result of the 2017 Tax Reform Act;

•	A $39 million decrease from rate adjustment clauses; and

102

•

•	An increase in sales to retail customers from an increase in cooling degree days ($33 million); and

•	A $21 million increase in sales to retail customers due to the effect of changes in customer usage and other factors ($8 million) and customer growth ($13 million).

Other operations and maintenance increased 16%, primarily reflecting:

•	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; partially offset by

•	An $18 million decrease from fewer planned outage days at certain generation facilities; and

•	An $11 million decrease in salaries, wages and benefits and general and administrative expenses.

Depreciation and amortization decreased 12%, primarily due to the retroactive application of depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements ($46 million), partially offset by various growth projects being placed into service ($16 million).

Income tax expense decreased 51%, primarily due to the 2017 Tax Reform Act ($69 million) and lower pre-tax income ($26 million).

Year-To-Date 2018 vs. 2017

Net revenue decreased 11%, 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 $91 million decrease for regulated generation and distribution operations as a result of the 2017 Tax Reform Act;

•

•	A $42 million decrease from rate adjustment clauses; 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 ($33 million); and

•	A $12 million increase in sales to retail customers due to customer growth ($25 million), partially offset by the effect of changes in customer usage and other factors ($13 million).

Other operations and maintenance increased 11%, primarily reflecting:

•	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; and

•	A $35 million increase due to storm damage and service restoration costs; partially offset by

•	A $22 million decrease in salaries, wages and benefits and general and administrative expenses; and

•	A $20 million decrease from fewer planned outage days at certain generation facilities.

Depreciation and amortization decreased 4%, primarily due to the retroactive application of depreciation rates for regulated nuclear plants to comply with the Virginia Commission requirements ($46 million), partially offset by various growth projects being placed into service ($23 million).

Other income decreased 45%, primarily related to Virginia Power’s electric transmission tower rental portfolio, including the absence of the assignment of such amounts to Vertical Bridge Towers II, LLC, ($13 million) and the absence of interest income associated with the settlement of state income tax refund claims ($11 million), partially offset by the absence of a charge associated with a customer settlement ($16 million).

Income tax expense decreased 64%, primarily due to lower pre-tax income ($141 million) and the 2017 Tax Reform Act ($98 million).

103

Dominion Energy Gas

Results of Operations

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

	Second Quarter							Year-To-Date
	2018		2017		$ Change			2018		2017		$ Change
(millions)
Net income	$	15	$	77	$	(62	)	$	181	$	185	$	(4	)

Overview

Second Quarter 2018 vs. 2017

Net income decreased 81%, primarily due to a charge for disallowance of FERC-regulated plant, partially offset by regulated natural gas transmission activities from growth projects placed into service.

Year-To-Date 2018 vs. 2017

Net income decreased 2%, primarily due to a charge for disallowance of FERC-regulated plant, partially offset by regulated natural gas transmission activities from growth projects placed into service and an increase in gains from agreements to convey shale development rights underneath several natural gas storage fields.

Analysis of Consolidated Operations

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

	Second Quarter							Year-To-Date
	2018		2017		$ Change			2018		2017		$ Change
(millions)
Operating revenue	$	459	$	422	$	37		$	985	$	912	$	73
Purchased gas		—		38		(38	)		29		81		(52	)
Other energy-related purchases		31		2		29			62		7		55
Net revenue		428		382		46			894		824		70
Other operations and maintenance		321		168		153			467		346		121
Depreciation and amortization		53		56		(3	)		112		110		2
Other taxes		47		43		4			107		97		10
Earnings from equity method investee		5		4		1			14		11		3
Other income		32		27		5			65		52		13
Interest and related charges		26		24		2			51		47		4
Income tax expense		3		45		(42	)		55		102		(47	)

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

Second Quarter 2018 vs. 2017

Net revenue increased 12%, primarily reflecting:

•	A $30 million increase in services performed for Atlantic Coast Pipeline; and

•	A $19 million increase due to regulated natural gas transmission growth projects placed in service; partially offset by

•	A $9 million decrease for regulated distribution operations as a result of the 2017 Tax Reform Act; and

•	A $7 million decrease from scheduled declines in certain DETI contracts.

Other operations and maintenance increased 91%, primarily reflecting:

•	A $134 million increase due to a charge for disallowance of FERC-regulated plant; and

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•	A $28 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 $15 million decrease from the absence of a charge to write-off the balance of a regulatory asset no longer considered probable of recovery; and

•	A $6 million decrease from gains related to agreements to convey shale development rights under natural gas storage fields.

Other income increased 19%, 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.

Income tax expense decreased 93%, primarily due to lower pre-tax income ($36 million) and the 2017 Tax Reform Act ($7 million).

Year-To-Date 2018 vs. 2017

Net revenue increased 8%, primarily reflecting:

•	A $45 million increase in services performed for Atlantic Coast Pipeline;

•	A $36 million increase due to regulated natural gas transmission growth projects placed in service; and

•	An $11 million increase in PIR program revenues; partially offset by

•	A $19 million decrease for regulated distribution operations as a result of the 2017 Tax Reform Act; and

•	A $14 million decrease from scheduled declines in certain DETI contracts.

Other operations and maintenance increased 35%, primarily reflecting:

•	A $134 million increase due to a charge for disallowance of FERC-regulated plant; and

•	A $44 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 $50 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.

Other taxes increased 10%, primarily due to increased property taxes related to growth projects placed into service ($5 million) and an increase in excise taxes ($3 million).

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.

Income tax expense decreased 46%, primarily due to the 2017 Tax Reform Act ($34 million) and lower pre-tax income ($18 million), partially offset by the absence of a settlement with state tax authorities ($5 million).

Liquidity and Capital Resources

Dominion Energy depends on both internal and external sources of liquidity to provide working capital and as a bridge to long-term debt financings. Short-term cash requirements not met by cash provided by operations are generally satisfied with proceeds from short-term borrowings. Long-term cash needs are met through issuances of debt and/or equity securities.

At June 30, 2018, Dominion Energy had $3.2 billion of unused capacity under its credit facility. See Note 15 to the Consolidated Financial Statements for more information.

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

	2018			2017
(millions)
Cash, restricted cash and equivalents at January 1	$	185		$	322
Cash flows provided by (used in):
Operating activities		2,425			2,360
Investing activities		(2,236	)		(3,321	)
Financing activities		(20	)		963
Net increase in cash, restricted cash and equivalents		169			2
Cash, restricted cash and equivalents at June 30	$	354		$	324

Operating Cash Flows

Net cash provided by Dominion Energy’s operating activities increased $65 million, primarily due to higher merchant generation margin, favorable impact of weather, the commencement of commercial operations of the Liquefaction Project and net changes in other working capital, partially offset by lower deferred fuel cost recoveries in the Virginia jurisdiction and increased interest expense.

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.

Credit Risk

Dominion Energy’s exposure to potential concentrations of credit risk results primarily from its energy marketing and price risk management activities. Presented below is a summary of Dominion Energy’s credit exposure as of June 30, 2018 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
(millions)
Investment grade⁽¹⁾	$	14	$	—	$	14
Non-investment grade⁽²⁾		3		—		3
No external ratings:
Internally rated—investment grade⁽³⁾		6		—		6
Internally rated—non-investment grade⁽⁴⁾		44		—		44
Total	$	67	$	—	$	67

(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 18% of the total net credit exposure.

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

(3)	The five largest counterparty exposures, combined, for this category represented approximately 9% of the total net credit exposure.

(4)	The five largest counterparty exposures, combined, for this category represented approximately 41% of the total net credit exposure.

Investing Cash Flows

Net cash used in Dominion Energy’s investing activities decreased $1.1 billion, primarily due to a decrease in plant construction and other property additions, a decrease in acquisitions of solar development projects and decreased contributions to the Atlantic Coast Pipeline.

Financing Cash Flows and Liquidity

Dominion Energy relies on capital markets as significant sources of funding for capital requirements not satisfied by cash provided by its operations. As discussed further in Credit Ratings and Debt Covenants in MD&A in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017, as updated in Current Report on Form 8-K, filed June 6, 2018, the ability to borrow funds or

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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 $20 million for the six months ended June 30, 2018, compared to net cash provided by financing activities of $963 million for the six months ended June 30, 2017, primarily due to lower net debt issuances, partially offset by higher issuance of common stock.

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 June 30, 2018 was $2 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.

Dominion Energy has announced its intention to pursue debt financing of the Cove Point LNG facility in the third quarter of 2018 and utilize the proceeds of up to $3 billion to repay outstanding debt at the parent company level. In addition, Dominion Energy announced its intention to pursue the divestiture of certain assets, potentially including its interest in Blue Racer, accounted for as an equity method investment.

See Note 15 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 June 30, 2018, 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 June 30, 2018, 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 June 30, 2018, 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 June 30, 2018, 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.

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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 in MD&A in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2018.

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 Report on Form 10-Q for the quarter ended March 31, 2018 and Note 16 in this report for additional information on various environmental matters.

Legal Matters

See Notes 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, Notes 13 and 16 to the Consolidated Financial Statements and Item 1. Legal Proceedings in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 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 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 Report on Form 10-Q for the quarter ended March 31, 2018 and Note 13 to the Consolidated Financial Statements in this report for additional information on various regulatory matters.

Significant Power Delivery Project

As part of the annual PJM regional transmission expansion plan process, PJM authorized additional electric transmission upgrade projects, including the Surry-to-Skiffes Creek-to-Whealton line, which is expected to cost approximately $390 million.

Significant Power Generation 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 commercial operations, which is expected by the end of 2018, and cost approximately $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.

Significant Gas Infrastructure Project

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 into service in late 2019. In July 2018, Cove Point announced it is evaluating a change to the location of a compressor station which could result in a delay of the in-service date and/or additional costs.

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

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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.

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ITEM 3.

QUANTITATIVE AND QUALITATIVE

DISCLOSURES ABOUT MARKET RISK

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

Market Risk Sensitive Instruments and Risk Management

The Companies’ financial instruments, commodity contracts and related financial derivative instruments are exposed to potential losses due to adverse changes in commodity prices, interest rates 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 $11 million and $5 million of Dominion Energy’s commodity-based derivative instruments as of June 30, 2018 and December 31, 2017, respectively.

A hypothetical 10% decrease in commodity prices would have resulted in a decrease in the fair value of $44 million and $51 million of Virginia Power’s commodity-based derivative instruments as of June 30, 2018 and December 31, 2017, respectively.

A hypothetical 10% increase in commodity prices would have resulted in a decrease in fair value of $5 million and $4 million of Dominion Energy Gas’ commodity-based derivative instruments as of June 30, 2018 and December 31, 2017, 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 $23 million and $12 million decrease in earnings at June 30, 2018 and December 31, 2017, 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 June 30, 2018 or December 31, 2017.

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The Companies also use interest rate derivatives, including forward-starting swaps, as cash flow hedges of forecasted interest payments. As of June 30, 2018, Dominion Energy, Virginia Power and Dominion Energy Gas had $4.4 billion, $1.6 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 $114 million, $79 million and $18 million, respectively, in the fair value of Dominion Energy, Virginia Power and Dominion Energy Gas’ interest rate derivatives at June 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.

Dominion Energy Gas holds foreign currency swaps for the purpose of hedging the foreign currency exchange risk associated with Euro denominated debt. As of June 30, 2018 and December 31, 2017, 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 $5 million and $6 million, in the fair value of Dominion Energy Gas' foreign currency swaps at June 30, 2018 and December 31, 2017, 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 loss on nuclear decommissioning and rabbi trust investments of $77 million for the six months ended June 30, 2018. Dominion Energy recognized net realized gains (including investment income) on nuclear decommissioning trust investments of $103 million for the six months ended June 30, 2017 and $167 million for the year ended December 31, 2017. 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 decrease in unrealized gains on debt investments of $38 million for the six months ended June 30, 2018 and recorded a net increase in unrealized gains on debt and equity investments of $157 million for the six months ended June 30, 2017 and $462 million for the year ended December 31, 2017.

Virginia Power recognized net investment loss on nuclear decommissioning trust investments of $35 million for the six months ended June 30, 2018. Virginia Power recognized net realized gains (including investment income) on nuclear decommissioning trust investments of $44 million for the six months ended June 30, 2017 and $76 million for the year ended December 31, 2017. 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 decrease in unrealized gains on debt investments of $20 million for the six months ended June 30, 2018 and recorded a net increase in unrealized gains on debt and equity investments of $73 million for the six months ended June 30, 2017 and $216 million for the year ended December 31, 2017.

Dominion Energy sponsors pension and other postretirement employee benefit plans that hold investments in trusts to fund employee benefit payments. Virginia Power and Dominion Energy Gas employees participate in these plans. Differences between actual and expected returns on plan assets are accumulated and amortized during future periods. As such, any investment-related declines in these trusts will result in future increases in the net periodic cost recognized for employee benefit plans and will be included in the determination of the amount of cash to be contributed to the employee benefit plans.

ITEM 4. CONTROLS AND PROCEDURES

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

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

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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 January 2016, Virginia Power self-reported a release of mineral oil from the Crystal City substation and began extensive cleanup. Virginia Power assumed the role of responsible party and has continued to cooperate with ongoing requirements for investigative and corrective action. In December 2016, the Virginia State Water Control Board approved a consent order between the VDEQ and Virginia Power related to this matter, which included a penalty in excess of $100,000. In May 2017, the VDEQ formally terminated the consent order, finding that all requirements had been completed. Also in May 2017, the U.S. Department of the Interior, on behalf of several federal and state agencies, proposed a settlement to resolve the agencies’ claims for natural resource damages related to the mineral oil release. In January 2018, Virginia Power and the natural resource trustee agencies executed a settlement agreement that would require Virginia Power to pay approximately $400,000 to fund wetland restoration and related projects in the location of the release. A 30-day public comment period on the settlement closed in March 2018. The settlement became final and effective in May 2018, and Virginia Power submitted the settlement payment in June 2018.

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 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 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, 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. 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.

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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⁾
4/1/18-4/30/18		252	$	67.43		—	19,629,059 shares/ $1.18 billion
5/1/18-5/31/18		—		—		—	19,629,059 shares/ $1.18 billion
6/1/18-6/30/18		1,337		63.40		—	19,629,059 shares/ $1.18 billion
Total		1,589	$	64.04		—	19,629,059 shares/ $1.18 billion

(1)	In April and June 2018, 252 shares and 1,337 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 5. OTHER INFORMATION

The following disclosure would have otherwise been filed on a Current Report on Form 8-K under Item 8.01 Other Events:

GHG Emissions

This section should be read in conjunction with information disclosed under the heading Environmental Strategy in Item 1. Business of the Companies’ Annual Report on Form 10-K for the year ended December 31, 2017.

Since 2000, Dominion Energy and Virginia Power have tracked the emissions of their electric generation fleet, which employs a mix of fuel and renewable energy sources. Comparing annual year 2017 to annual year 2000, the entire electric generating fleet (based on ownership percentage) reduced its average CO₂ emissions rate per MWh of energy produced from electric generation by approximately 50%. Comparing annual year 2017 to annual year 2000, the regulated electric generating fleet (based on ownership percentage) reduced its average CO₂ emissions rate per MWh of energy produced from electric generation by approximately 35%.

Dominion Energy also develops a comprehensive GHG inventory annually. For Power Generation, Dominion Energy’s and Virginia Power’s direct CO₂ equivalent emissions (based on ownership percentage) were 30.1 million metric tons and 26.4 million metric tons, respectively, in 2017, compared to 37.2 million metric tons and 33.1 million metric tons, respectively, in 2016. The corresponding Power Generation carbon intensity rates for Dominion Energy were 0.295 metric tons CO₂ equivalent emissions per net MWh in 2017 and 0.339 metric tons CO₂ equivalent emissions per net MWh in 2016.

For Power Delivery’s regulated electric transmission and distribution operations, direct CO₂ equivalent emissions for 2017 were 37,841 metric tons, compared to 42,847 metric tons in 2016.

Dominion Energy’s natural gas companies have been reporting GHG emissions to the EPA since 2011 under the GHG Reporting Program. In January 2016, the GHG Reporting Program was expanded to also include GHG inputs and emissions associated with natural gas gathering and boosting sources and transmission pipeline blowdowns for facilities that exceed 25,000 metric tons per year of CO₂ equivalent emissions. The sources within these new facilities were not previously covered under the rule and the first reports for these new sources were submitted to the EPA on March 31, 2017.

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The Companies’ GHG inventory follows all methodologies specified in the EPA Mandatory Greenhouse Gas Reporting Rule, 40 Code of Federal Regulations Part 98 for calculating emissions. Total CO₂ equivalent emissions reported for our natural gas assets, as estimated in Dominion Energy’s corporate inventory, were 3.51 million metric tons in 2017. This estimate includes emissions reported under the GHG Reporting Program, as well as other emissions not required to be reported under the federal program. The 2017 corporate GHG inventory emission estimate includes Dominion Energy Questar Pipeline, Questar Gas and Wexpro Company for the entire calendar year. Dominion Energy’s 2017 methane emissions reported under Subpart W of the Greenhouse Gas Reporting Rule are as follows:

Subpart W Segment	Subpart W Total CH4 Emissions (mcf CH4)
Distribution		1,668,183
Production		762,788
Transmission pipelines		396,720
Transmission compressor stations		147,565
Gathering and boosting		144,188
Storage		53,748
LNG import/export		6,444
Processing		916

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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 12, 2013 (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 (filed herewith); Fifteenth Supplemental Indenture, dated June 1, 2018 (Exhibit 4.2, Form 8-K, filed June 5, 2018, File No. 1-8489).	X

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4.3	Indenture, dated as of October 1, 2013, between Dominion Gas Holdings, LLC and Deutsche Bank Trust Company Americas, as Trustee (Exhibit 4.1, Form S-4 filed April 4, 2014, File No. 333-195066); Second Supplemental Indenture, dated as of October 1, 2013 (Exhibit 4.3, Form S-4 filed April 4, 2014, File No. 333-195066); Third Supplemental Indenture, dated as of October 1, 2013 (Exhibit 4.4, Form S-4 filed April 4, 2014, File No. 333-195066); Fourth Supplemental Indenture, dated as of December 1, 2014 (Exhibit 4.2, Form 8-K filed December 8, 2014, File No. 333-195066); Fifth Supplemental Indenture, dated as of December 1, 2014 (Exhibit 4.3, Form 8-K filed December 8, 2014, File No. 333-195066); Sixth Supplemental Indenture, dated as of December 1, 2014 (Exhibit 4.4, Form 8-K filed December 8, 2014, File No. 333-195066); Seventh Supplemental Indenture, dated as of November 1, 2015 (Exhibit 4.2, Form 8-K filed November 17, 2015, File No. 001-37591); Eighth Supplemental Indenture, dated as of May 1, 2016 (Exhibit 4.1.a, Form 10-Q filed August 3, 2016, File No. 1-37591); Ninth Supplemental Indenture, dated as of June 1, 2016 (Exhibit 4.1.b, Form 10-Q filed August 3, 2016, File No. 1-37591); Tenth Supplemental Indenture, dated as of June 1, 2016 (Exhibit 4.1.c, Form 10-Q filed August 3, 2016, File No. 1-37591); Eleventh Supplemental Indenture, dated June 1, 2018 (Exhibit 4.2, Form 8-K filed June 19, 2018, File No. 1-37591).	X		X

10.1	$500,000,000 364-Day Term Loan Credit Agreement, dated June 14, 2018, by and among Dominion Energy, Inc., Toronto Dominion (Texas) LLC, as Administrative Agent, TD Securities (USA) LLC, as Lead Arranger and Bookrunner, and other lenders named therein (Exhibit 10.1, Form 8-K filed June 15, 2018, File No. 001-08489).	X


12.1	Ratio of earnings to fixed charges for Dominion Energy, Inc. (filed herewith).	X

12.2	Ratio of earnings to fixed charges for Virginia Electric and Power Company (filed herewith).		X

12.3	Ratio of earnings to fixed charges for Dominion Energy Gas Holdings, LLC (filed herewith).			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

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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 June 30, 2018, filed on August 2, 2018, 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 June 30, 2018, filed on August 2, 2018, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income, (iii) Consolidated Balance Sheets, (iv) Consolidated Statement of Common Shareholder’s Equity (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements. The following financial statements from Dominion Energy Gas Holdings, LLC’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2018, filed on August 2, 2018, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Statements of Comprehensive Income, (iii) Consolidated Balance Sheets, (iv) Consolidated Statement of Equity, (v) Consolidated Statements of Cash Flows, and (vi) the Notes to Consolidated Financial Statements.	X	X	X

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SIGNATURE

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


	DOMINION ENERGY, INC. Registrant

August 2, 2018	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

	VIRGINIA ELECTRIC AND POWER COMPANY Registrant

August 2, 2018	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

	DOMINION ENERGY GAS HOLDINGS, LLC Registrant

August 2, 2018	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

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