10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark one)

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

For the quarterly period ended June 30, 2016

or

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

For the transition period from                      to                     

Commission File Number	Exact name of registrants as specified in their charters, address of principal executive offices and registrants’ telephone number	I.R.S. Employer Identification Number
001-08489	DOMINION RESOURCES, INC.	54-1229715
000-55337	VIRGINIA ELECTRIC AND POWER COMPANY	54-0418825
001-37591	DOMINION 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 Resources, Inc.    Yes  x    No  ¨                         Virginia Electric and Power Company    Yes  x    No  ¨

Dominion Gas Holdings, LLC    Yes  x    No  ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

Dominion Resources, Inc.    Yes  x    No  ¨                         Virginia Electric and Power Company    Yes  x    No  ¨

Dominion Gas Holdings, LLC    Yes  x    No  ¨

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

Dominion Resources, Inc.

Large accelerated filer	x	Accelerated filer	¨
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	Smaller reporting company	¨

Virginia Electric and Power Company

Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	x  (Do not check if a smaller reporting company)	Smaller reporting company	¨

Dominion Gas Holdings, LLC

Large accelerated filer	¨	Accelerated filer	¨
Non-accelerated filer	x  (Do not check if a smaller reporting company)	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 Resources, Inc.    Yes  ¨    No  x                         Virginia Electric and Power Company    Yes  ¨    No  x

Dominion Gas Holdings, LLC    Yes  ¨    No  x

At July 15, 2016, the latest practicable date for determination, Dominion Resources, Inc. had 625,763,030 shares of common stock outstanding and Virginia Electric and Power Company had 274,723 shares of common stock outstanding. Dominion Resources, Inc. is the sole holder of Virginia Electric and Power Company’s common stock. Dominion Resources, Inc. holds all of the membership interests of Dominion Gas Holdings, LLC.

This combined Form 10-Q represents separate filings by Dominion Resources, Inc., Virginia Electric and Power Company and Dominion 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 Gas Holdings, LLC make no representations as to the information relating to Dominion Resources, Inc.’s other operations.

VIRGINIA ELECTRIC AND POWER COMPANY AND DOMINION 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		6
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations		79
Item 3.	Quantitative and Qualitative Disclosures About Market Risk		93
Item 4.	Controls and Procedures		95
	PART II. Other Information
Item 1.	Legal Proceedings		96
Item 1A.	Risk Factors		96
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		96
Item 6.	Exhibits		97

2

GLOSSARY OF TERMS

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

Abbreviation or Acronym	Definition
2013 Equity Units	Dominion’s 2013 Series A Equity Units and 2013 Series B Equity Units issued in June 2013
2014 Equity Units	Dominion’s 2014 Series A Equity Units issued in July 2014
AFUDC	Allowance for funds used during construction
AMR	Automated meter reading program deployed by East Ohio
AOCI	Accumulated other comprehensive income (loss)
APCo	Appalachian Power Company
AROs	Asset retirement obligations
ARP	Acid Rain Program, a market-based initiative for emissions allowance trading, established pursuant to Title IV of the CAA
Atlantic Coast Pipeline	Atlantic Coast Pipeline, LLC, a limited liability company owned by Dominion, Duke Energy Corporation, Piedmont Natural Gas Company, Inc. and AGL Resources Inc.
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 and Caiman Energy II, LLC
BREDL	Blue Ridge Environmental Defense League
Brunswick County	A 1,358 MW combined cycle, natural gas-fired power station in Brunswick County, Virginia
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
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
COL	Combined Construction Permit and Operating License
Columbia to Eastover Project	Project to provide 15,800 Dths/day of firm transportation service from an existing interconnect with Southern Natural Gas Company, LLC in Aiken County, South Carolina and provide for a receipt point change of 2,200 Dths/day under an existing contract from an existing interconnect with Transco in Cherokee County, South Carolina for a total 18,000 Dths/day, to a new delivery point for the International Paper Company at its pulp and paper mill known as the Eastover Plant in Richland County, South Carolina
Companies	Dominion, Virginia Power and Dominion 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 Cove Point LNG, LP
CPCN	Certificate of Public Convenience and Necessity
CSAPR	Cross State Air Pollution Rule
CWA	Clean Water Act
DCG	Dominion Carolina Gas Transmission, LLC (successor by statutory conversion to and formerly known as Carolina Gas Transmission Corporation)
DEI	Dominion Energy, Inc.
Dominion	The legal entity, Dominion Resources, Inc., one or more of its consolidated subsidiaries (other than Virginia Power and Dominion Gas) or operating segments or the entirety of Dominion Resources, Inc. and its consolidated subsidiaries
Dominion Gas	The legal entity, Dominion Gas Holdings, LLC, one or more of its consolidated subsidiaries or operating segment, or the entirety of Dominion Gas Holdings, LLC and its consolidated subsidiaries
Dominion Iroquois	Dominion Iroquois, Inc., which, as of May 2016, holds a 24.07% noncontrolling partnership interest in Iroquois
Dominion Midstream	The legal entity, Dominion Midstream Partners, LP, one or more of its consolidated subsidiaries, Cove Point Holdings, Iroquois GP Holding Company, LLC and DCG (beginning April 1, 2015), or the entirety of Dominion Midstream Partners, LP, and its consolidated subsidiaries
DRS	Dominion Resources Services, Inc.

3

Abbreviation or Acronym	Definition
Dth	Dekatherm
DTI	Dominion Transmission, Inc.
DVP	Dominion Virginia Power operating segment
East Ohio	The East Ohio Gas Company, doing business as Dominion East Ohio
EPA	Environmental Protection Agency
EPS	Earnings per share
FERC	Federal Energy Regulatory Commission
Four Brothers	Four Brothers Solar, LLC, a limited liability company owned by Dominion and Four Brothers Holdings, LLC, a wholly-owned subsidiary of SunEdison
Fowler Ridge	A wind-turbine facility joint venture between Dominion and BP Wind Energy North America Inc. in Benton County, Indiana
FTRs	Financial transmission rights
GAAP	United States generally accepted accounting principles
Gal	Gallon
GHG	Greenhouse gas
Granite Mountain	Granite Mountain Holdings, LLC, a limited liability company owned by Dominion and Granite Mountain Renewables, LLC, a wholly-owned subsidiary of SunEdison
Greensville County	An approximately 1,588 MW proposed 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 Hope
Iron Springs	Iron Springs Holdings, LLC, a limited liability company owned by Dominion and Iron Springs Renewables, LLC, a wholly-owned subsidiary of SunEdison
Iroquois	Iroquois Gas Transmission System, L.P.
ISO-NE	Independent System Operator New England
July 2016 hybrids	2016 Series A Enhanced Junior Subordinated Notes due 2076
June 2006 hybrids	2006 Series A Enhanced Junior Subordinated Notes due 2066
kV	Kilovolt
Liquefaction Project	A natural gas export/liquefaction facility currently under construction by Cove Point
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
MISO	Midcontinent Independent Transmission System Operator, Inc.
MW	Megawatt
MWh	Megawatt hour
NedPower	A wind-turbine facility joint venture between Dominion and Shell Wind Energy, Inc. in Grant County, West Virginia
NGLs	Natural gas liquids
NOx	Nitrogen oxide
NRC	Nuclear Regulatory Commission
NSPS	New Source Performance Standards
Ohio Commission	Public Utilities Commission of Ohio
Order 1000	Order issued by FERC adopting new 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.
ppb	Parts-per-billion
PREP	Pipeline Replacement and Expansion Program, a program of replacing, upgrading and expanding natural gas utility infrastructure to be deployed by Hope
PSD	Prevention of Significant Deterioration

4

Abbreviation or Acronym	Definition
Questar	The legal entity, Questar Corporation, one or more of its consolidated subsidiaries, or operating segments, or the entirety of Questar Corporation and its consolidated subsidiaries
Questar Combination	Agreement and plan of merger entered on January 31, 2016 between Dominion and Questar in which Questar will become a wholly-owned subsidiary of Dominion upon closing
REIT	Real estate investment trust
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
Rider W	A rate adjustment clause associated with the recovery of costs related to Warren County
ROE	Return on equity
RSN	Remarketable subordinated note
Scott Solar	An approximately 17 MW proposed utility-scale solar power station in Powhatan County, Virginia
SEC	Securities and Exchange Commission
September 2006 hybrids	2006 Series B Enhanced Junior Subordinated Notes due 2066
SO2	Sulfur dioxide
Standard & Poor’s	Standard & Poor’s Ratings Services, a division of McGraw Hill Financial, Inc.
SunEdison	The legal entity, SunEdison, Inc., one or more of its consolidated subsidiaries (including Four Brothers Holdings, LLC, Granite Mountain Renewables, LLC and Iron Springs Renewables, LLC) or operating segments, or the entirety of SunEdison, Inc. and its consolidated subsidiaries
Terra Nova Renewable Partners	A partnership between SunEdison and institutional investors advised by J.P. Morgan Asset Management-Global Real Assets
Three Cedars	Granite Mountain and Iron Springs, collectively
TransCanada	The legal entity, TransCanada Corporation, one or more of its consolidated subsidiaries, or operating segments, or the entirety of TransCanada Corporation and its consolidated subsidiaries
UAO	Unilateral Administrative Order
UEX Rider	Uncollectible Expense Rider deployed by East Ohio
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 Power and its consolidated subsidiaries
VOC	Volatile organic compounds
Warren County	A 1,342 MW combined-cycle, natural gas-fired power station in Warren County, Virginia
Whitehouse	An approximately 20 MW proposed utility-scale solar power station in Louisa County, Virginia
Woodland	An approximately 19 MW proposed utility-scale solar power station in Isle of Wight County, Virginia

5

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions, except per share amounts)
Operating Revenue	$	2,598	$	2,747	$	5,519	$	6,156
Operating Expenses
Electric fuel and other energy-related purchases		551		591		1,185		1,544
Purchased electric capacity		45		90		113		184
Purchased gas		56		111		175		361
Other operations and maintenance		665		709		1,368		1,311
Depreciation, depletion and amortization		361		339		712		682
Other taxes		139		134		303		299
Total operating expenses		1,817		1,974		3,856		4,381
Income from operations		781		773		1,663		1,775
Other income		72		56		126		116
Interest and related charges		239		221		465		444
Income from operations including noncontrolling interests before income tax expense		614		608		1,324		1,447
Income tax expense		152		190		331		489
Net Income Including Noncontrolling Interests		462		418		993		958
Noncontrolling Interests		10		5		17		9
Net Income Attributable to Dominion	$	452	$	413	$	976	$	949
Earnings Per Common Share
Net income attributable to Dominion - Basic	$	0.73	$	0.70	$	1.61	$	1.61
Net income attributable to Dominion - Diluted		0.73		0.70		1.61		1.60
Dividends Declared Per Common Share	$	0.7000	$	0.6475	$	1.4000	$	1.2950

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

6

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Net income including noncontrolling interests	$	462		$	418		$	993		$	958
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities(1)		(11	)		92			42			34
Changes in unrealized net gains (losses) on investment securities(2)		26			(11	)		41			4
Changes in unrecognized pension and other postretirement benefit costs(3)		—			3			—			3
Amounts reclassified to net income:
Net derivative gains-hedging activities(4)		(44	)		(61	)		(107	)		(2	)
Net realized gains on investment securities(5)		(8	)		(12	)		(10	)		(33	)
Net pension and other postretirement benefit costs(6)		8			12			16			25
Changes in other comprehensive loss from equity method investees(7)		(1	)		—			(1	)		(1	)
Total other comprehensive income (loss)		(30	)		23			(19	)		30
Comprehensive income including noncontrolling interests		432			441			974			988
Comprehensive income attributable to noncontrolling interests		10			5			17			9
Comprehensive income attributable to Dominion	$	422		$	436		$	957		$	979

(1) Net of $7 million and $(59) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(26) million and $(19) million tax for the six months ended June 30, 2016 and 2015, respectively.

(2) Net of $(15) million and $6 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(25) million and $(5) million tax for the six months ended June 30, 2016 and 2015, respectively.

(3) Net of $— million and $3 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $—- million and $3 million tax for the six months ended June 30, 2016 and 2015, respectively.

(4) Net of $28 million and $41 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $67 million and $2 million tax for the six months ended June 30, 2016 and 2015, respectively.

(5) Net of $5 million and $8 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $6 million and $20 million tax for the six months ended June 30, 2016 and 2015, respectively.

(6) Net of $(6) million and $(9) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(12) million and $(18) million tax for the six months ended June 30, 2016 and 2015, respectively.

(7) Net of $— million and $1 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $— million and $1 million tax for the six months ended June 30, 2016 and 2015, respectively.

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

7

DOMINION RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30,      2016			December 31, 2015(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	377		$	607
Restricted cash and cash equivalents		516			17
Customer receivables (less allowance for doubtful accounts of $19 and $32)		1,140			1,200
Other receivables (less allowance for doubtful accounts of $3 and $2)		139			169
Inventories		1,351			1,348
Prepayments		143			198
Other		477			650
Total current assets		4,143			4,189
Investments
Nuclear decommissioning trust funds		4,331			4,183
Investment in equity method affiliates		1,372			1,320
Other		277			271
Total investments		5,980			5,774
Property, Plant and Equipment
Property, plant and equipment		60,490			57,776
Accumulated depreciation, depletion and amortization		(16,808	)		(16,222	)
Total property, plant and equipment, net		43,682			41,554
Deferred Charges and Other Assets
Goodwill		3,294			3,294
Pension and other postretirement benefit assets		1,017			943
Regulatory assets		2,150			1,865
Other		1,103			1,029
Total deferred charges and other assets		7,564			7,131
Total assets	$	61,369		$	58,648

(1) Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

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

8

DOMINION RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30,      2016			December 31, 2015(1)
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	1,348		$	1,825
Short-term debt		3,437			3,509
Accounts payable		589			726
Accrued interest, payroll and taxes		561			515
Other(2)		1,331			1,544
Total current liabilities		7,266			8,119
Long-Term Debt
Long-term debt		21,406			20,048
Junior subordinated notes		2,399			1,340
Remarketable subordinated notes		982			2,080
Total long-term debt		24,787			23,468
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		7,666			7,414
Asset retirement obligations		1,941			1,887
Regulatory liabilities		2,318			2,285
Other		1,939			1,873
Total deferred credits and other liabilities		13,864			13,459
Total liabilities		45,917			45,046
Commitments and Contingencies (see Note 15)
Equity
Common stock – no par(3)		8,160			6,680
Retained earnings		6,585			6,458
Accumulated other comprehensive loss		(493	)		(474	)
Total common shareholders’ equity		14,252			12,664
Noncontrolling interests		1,200			938
Total equity		15,452			13,602
Total liabilities and equity	$	61,369		$	58,648

(1) Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

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

(3) 1 billion shares authorized; 617 million shares and 596 million shares outstanding at June 30, 2016 and December 31, 2015, respectively.

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

9

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENT OF EQUITY

(Unaudited)

	Common Stock					Dominion Shareholders
	Shares		Amount			Retained Earnings			Accumulated Other Comprehensive Loss			Total Common Shareholders’ Equity			Noncontrolling Interests			Total Equity
(millions)
December 31, 2015		596	$	6,680		$	6,458		$	(474	)	$	12,664		$	938		$	13,602
Net income including noncontrolling interests							976						976			17			993
Contributions from SunEdison to Four Brothers and Three Cedars													—			162			162
Sale of interest in merchant solar projects				22									22			117			139
Purchase of Dominion Midstream common units				(2	)								(2	)		(11	)		(13	)
Issuance of common stock		21		1,458									1,458						1,458
Stock awards (net of change in unearned compensation)				6									6						6
Dividends and distributions							(849	)					(849	)		(23	)		(872	)
Other comprehensive loss, net of tax										(19	)		(19	)					(19	)
Other				(4	)								(4	)					(4	)
June 30, 2016		617	$	8,160		$	6,585		$	(493	)	$	14,252		$	1,200		$	15,452

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

10

DOMINION RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2016			2015
(millions)
Operating Activities
Net income including noncontrolling interests	$	993		$	958
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation, depletion and amortization (including nuclear fuel)		853			822
Deferred income taxes and investment tax credits		275			399
Gains on the sales of assets and equity method investment in Iroquois		(45	)		(71	)
Other adjustments		(27	)		(18	)
Changes in:
Accounts receivable		82			214
Inventories		(3	)		47
Deferred fuel and purchased gas costs, net		114			28
Prepayments		55			47
Accounts payable		(92	)		(173	)
Accrued interest, payroll and taxes		46			(41	)
Margin deposit assets and liabilities		(13	)		186
Other operating assets and liabilities		(220	)		(238	)
Net cash provided by operating activities		2,018			2,160
Investing Activities
Plant construction and other property additions (including nuclear fuel)		(3,160	)		(2,370	)
Acquisition of solar development projects		—			(230	)
Acquisition of DCG		—			(497	)
Proceeds from sales of securities		709			580
Purchases of securities		(752	)		(553	)
Restricted cash and cash equivalents		(500	)		—
Proceeds from assignments of shale development rights		5			28
Other		(27	)		(42	)
Net cash used in investing activities		(3,725	)		(3,084	)
Financing Activities
Repayment of short-term debt, net		(72	)		(153	)
Repayment and repurchase of short-term notes		(600	)		—
Issuance of long-term debt		1,930			1,200
Repayment and repurchase of long-term debt		(500	)		(8	)
Proceeds from sale of interest in merchant solar projects		117			—
Contributions from SunEdison to Four Brothers and Three Cedars		162			—
Issuance of common stock		1,458			647
Common dividend payments		(849	)		(765	)
Other		(169	)		(44	)
Net cash provided by financing activities		1,477			877
Decrease in cash and cash equivalents		(230	)		(47	)
Cash and cash equivalents at beginning of period		607			318
Cash and cash equivalents at end of period	$	377		$	271
Supplemental Cash Flow Information
Significant noncash investing and financing activities(1):
Accrued capital expenditures	$	257		$	319

(1) See Note 14 for noncash financing activities related to the remarketing of RSNs.

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

11

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Operating Revenue(1)	$	1,776	$	1,813	$	3,666	$	3,950
Operating Expenses
Electric fuel and other energy-related purchases(1)		475		497		1,011		1,307
Purchased electric capacity		45		90		113		184
Other operations and maintenance:
Affiliated suppliers		64		69		165		144
Other		322		376		671		697
Depreciation and amortization		247		231		495		469
Other taxes		70		69		144		143
Total operating expenses		1,223		1,332		2,599		2,944
Income from operations		553		481		1,067		1,006
Other income		18		21		34		36
Interest and related charges		113		108		227		216
Income before income tax expense		458		394		874		826
Income tax expense		178		148		331		311
Net Income	$	280	$	246	$	543	$	515

(1) See Note 17 for amounts attributable to affiliates.

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

12

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Net income	$	280		$	246		$	543		$	515
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities(1)		(6	)		7			(15	)		3
Changes in unrealized net gains on nuclear decommissioning trust funds(2)		3			—			6			1
Amounts reclassified to net income:
Net derivative losses-hedging activities(3)		—			—			—			1
Net realized gains on nuclear decommissioning trust funds(4)		(1	)		(2	)		(1	)		(3	)
Total other comprehensive income (loss)		(4	)		5			(10	)		2
Comprehensive income	$	276		$	251		$	533		$	517

(1) Net of $4 million and $(4) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $9 million and $(2) million tax for the six months ended June 30, 2016 and 2015, respectively.

(2) Net of $(3) million and $1 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(4) million and $— million tax for the six months ended June 30, 2016 and 2015, respectively.

(3) Net of $— million tax for both the three months ended June 30, 2016 and 2015, and net of $(1) million and $— million tax for the six months ended June 30, 2016 and 2015, respectively.

(4) Net of $1 million tax for both the three months ended June 30, 2016 and 2015, and net of $1 million tax for both the six months ended June 30, 2016 and 2015.

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

13

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30,      2016			December 31, 2015(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	61		$	18
Customer receivables (less allowance for doubtful accounts of $13 and $27)		837			822
Other receivables (less allowance for doubtful accounts of $1 at both dates)		79			109
Affiliated receivables		2			296
Inventories (average cost method)		860			873
Prepayments		73			38
Regulatory assets		193			326
Other(2)		39			22
Total current assets		2,144			2,504
Investments
Nuclear decommissioning trust funds		2,030			1,945
Other		4			3
Total investments		2,034			1,948
Property, Plant and Equipment
Property, plant and equipment		38,734			37,639
Accumulated depreciation and amortization		(12,076	)		(11,708	)
Total property, plant and equipment, net		26,658			25,931
Deferred Charges and Other Assets
Regulatory assets		966			667
Other(2)		591			515
Total deferred charges and other assets		1,557			1,182
Total assets	$	32,393		$	31,565

(1) Virginia Power’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

(2) See Note 17 for amounts attributable to affiliates.

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

14

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30,      2016		December 31, 2015(1)
(millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Securities due within one year	$	99	$	476
Short-term debt		1,423		1,656
Accounts payable		311		366
Payables to affiliates		74		73
Affiliated current borrowings		—		376
Accrued interest, payroll and taxes		229		190
Regulatory liabilities		112		35
Other(2)		585		558
Total current liabilities		2,833		3,730
Long-Term Debt		9,562		8,892
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		4,885		4,654
Asset retirement obligations		1,154		1,104
Regulatory liabilities		1,956		1,929
Other(2)		829		615
Total deferred credits and other liabilities		8,824		8,302
Total liabilities		21,219		20,924
Commitments and Contingencies (see Note 15)
Common Shareholder’s Equity
Common stock – no par(3)		5,738		5,738
Other paid-in capital		1,113		1,113
Retained earnings		4,293		3,750
Accumulated other comprehensive income		30		40
Total common shareholder’s equity		11,174		10,641
Total liabilities and shareholder’s equity	$	32,393	$	31,565

(1) Virginia Power’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

(2) See Note 17 for amounts attributable to affiliates.

(3) 500,000 shares authorized; 274,723 shares outstanding at June 30, 2016 and December 31, 2015.

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

15

VIRGINIA ELECTRIC AND POWER COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2016			2015
(millions)
Operating Activities
Net income	$	543		$	515
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)		589			555
Deferred income taxes and investment tax credits		228			13
Other adjustments		(11	)		(6	)
Changes in:
Accounts receivable		7			40
Affiliated receivables and payables		295			1
Inventories		13			25
Prepayments		(35	)		229
Deferred fuel expenses, net		105			(9	)
Accounts payable		(10	)		(9	)
Accrued interest, payroll and taxes		39			38
Other operating assets and liabilities		(61	)		2
Net cash provided by operating activities		1,702			1,394
Investing Activities
Plant construction and other property additions		(1,226	)		(1,292	)
Purchases of nuclear fuel		(78	)		(67	)
Proceeds from sales of securities		347			209
Purchases of securities		(373	)		(222	)
Other		(6	)		(27	)
Net cash used in investing activities		(1,336	)		(1,399	)
Financing Activities
Issuance (repayment) of short-term debt, net		(233	)		80
Repayment of affiliated current borrowings, net		(376	)		(427	)
Issuance of long-term debt		750			700
Repayment of long-term debt		(457	)		(6	)
Common dividend payments to parent		—			(270	)
Other		(7	)		(5	)
Net cash provided by (used in) financing activities		(323	)		72
Increase in cash and cash equivalents		43			67
Cash and cash equivalents at beginning of period		18			15
Cash and cash equivalents at end of period	$	61		$	82
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	142		$	117

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

16

DOMINION GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Operating Revenue(1)	$	368	$	395	$	799	$	926
Operating Expenses
Purchased gas(1)		16		21		50		95
Other energy-related purchases		1		7		4		13
Other operations and maintenance:
Affiliated suppliers		16		17		43		38
Other		58		107		155		160
Depreciation and amortization		52		53		95		104
Other taxes		39		37		91		92
Total operating expenses		182		242		438		502
Income from operations		186		153		361		424
Other income		9		4		15		13
Interest and related charges		23		18		45		35
Income from operations before income taxes		172		139		331		402
Income tax expense		67		54		128		156
Net Income	$	105	$	85	$	203	$	246

(1) See Note 17 for amounts attributable to related parties.

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

17

DOMINION GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Net income	$	105		$	85		$	203		$	246
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities(1)		(9	)		3			(15	)		(1	)
Amounts reclassified to net income:
Net derivative gains-hedging activities(2)		—			(1	)		(2	)		(1	)
Net pension and other postretirement benefit costs(3)		1			1			1			2
Total other comprehensive income (loss)		(8	)		3			(16	)		—
Comprehensive income	$	97		$	88		$	187		$	246

(1) Net of $4 million and $(1) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $8 million and $1 million tax for the six months ended June 30, 2016 and 2015, respectively.

(2) Net of $(2) million and $— million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $— million tax for both the six months ended June 30, 2016 and 2015.

(3) Net of $— million and $(1) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(1) million and $(2) million tax for the six months ended June 30, 2016 and 2015, respectively.

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

18

DOMINION GAS HOLDINGS, LLC

CONSOLIDATED BALANCE SHEETS

(Unaudited)

	June 30,      2016			December 31, 2015(1)
(millions)
ASSETS
Current Assets
Cash and cash equivalents	$	226		$	13
Customer receivables (less allowance for doubtful accounts of $1 at both dates)(2)		176			219
Other receivables (less allowance for doubtful accounts of $2 at both dates)(2)		11			7
Affiliated receivables		6			98
Inventories		90			78
Prepayments		59			88
Other(2)		56			63
Total current assets		624			566
Investments		99			104
Property, Plant and Equipment
Property, plant and equipment		10,053			9,693
Accumulated depreciation and amortization		(2,766	)		(2,690	)
Total property, plant and equipment, net		7,287			7,003
Deferred Charges and Other Assets
Goodwill		542			542
Pension and other postretirement benefit assets(2)		1,579			1,510
Other(2)		604			583
Total deferred charges and other assets		2,725			2,635
Total assets	$	10,735		$	10,308

(1) Dominion Gas’ Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

(2) See Note 17 for amounts attributable to related parties.

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

19

DOMINION GAS HOLDINGS, LLC

CONSOLIDATED BALANCE SHEETS—(Continued)

(Unaudited)

	June 30,      2016			December 31, 2015(1)
(millions)
LIABILITIES AND EQUITY
Current Liabilities
Securities due within one year	$	400		$	400
Short-term debt		238			391
Accounts payable		124			201
Payables to affiliates		17			22
Affiliated current borrowings		—			95
Accrued interest, payroll and taxes		155			183
Other(2)		161			183
Total current liabilities		1,095			1,475
Long-Term Debt		3,541			2,869
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,331			2,214
Other(2)		412			432
Total deferred credits and other liabilities		2,743			2,646
Total liabilities		7,379			6,990
Commitments and Contingencies (see Note 15)
Equity
Membership interests		3,471			3,417
Accumulated other comprehensive loss(2)		(115	)		(99	)
Total equity		3,356			3,318
Total liabilities and equity	$	10,735		$	10,308

(1) Dominion Gas’ Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

(2) See Note 17 for amounts attributable to related parties.

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

20

DOMINION GAS HOLDINGS, LLC

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

Six Months Ended June 30,	2016			2015
(millions)
Operating Activities
Net income	$	203		$	246
Adjustments to reconcile net income to net cash provided by operating activities:
Gains on the sales of assets and equity method investment in Iroquois		(45	)		(71	)
Depreciation and amortization		95			104
Deferred income taxes and investment tax credits		125			55
Other adjustments		4			—
Changes in:
Accounts receivable		39			106
Affiliated receivables and payables		87			(15	)
Deferred purchased gas costs, net		11			28
Prepayments		29			111
Accounts payable		(75	)		(132	)
Accrued interest, payroll and taxes		(28	)		(54	)
Other operating assets and liabilities		(120	)		(85	)
Net cash provided by operating activities		325			293
Investing Activities
Plant construction and other property additions		(393	)		(292	)
Proceeds from sale of equity method investment in Iroquois		7			—
Proceeds from assignments of shale development rights		5			28
Other		(5	)		(6	)
Net cash used in investing activities		(386	)		(270	)
Financing Activities
Issuance (repayment) of short-term debt, net		(153	)		360
Issuance of long-term debt		680			—
Repayment of affiliated current borrowings, net		(95	)		(216	)
Distribution payments to parent		(150	)		(164	)
Other		(8	)		(1	)
Net cash provided by (used in) financing activities		274			(21	)
Increase in cash and cash equivalents		213			2
Cash and cash equivalents at beginning of period		13			9
Cash and cash equivalents at end of period	$	226		$	11
Supplemental Cash Flow Information
Significant noncash investing activities:
Accrued capital expenditures	$	42		$	37

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

21

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Note 1. Nature of Operations

Dominion, headquartered in Richmond, Virginia, is one of the nation’s largest producers and transporters of energy. Dominion’s operations are conducted through various subsidiaries, including Virginia Power and Dominion Gas. Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina. Dominion 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. Dominion Gas’ principal wholly-owned subsidiaries are DTI, East Ohio and Dominion Iroquois. In August 2016, DTI transferred its gathering and processing facilities to Dominion Gathering and Processing, Inc., a newly-formed wholly-owned subsidiary of Dominion Gas.

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, 2015.

In the Companies’ opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of June 30, 2016, their results of operations for the three and six months ended June 30, 2016 and 2015, their cash flows for the six months ended June 30, 2016 and 2015 and Dominion’s statement of equity for the six months ended June 30, 2016. 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. As of June 30, 2016, Dominion owns the general partner and 64.8% of the limited partner interests in Dominion Midstream. The public’s ownership interest in Dominion Midstream is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements. Also, as of June 30, 2016, Dominion owns 50% of the units in and consolidates Four Brothers and Three Cedars. SunEdison’s ownership interest in Four Brothers and Three Cedars, as well as Terra Nova Renewable Partners’ 33% interest in certain Dominion merchant solar projects, is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements. See Note 3 for further information on transactions with SunEdison.

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’ 2015 Consolidated Financial Statements and Notes have been reclassified to conform to the 2016 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows, except for the reclassification of debt issuance costs as discussed in Note 2 to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2015.

Amounts disclosed for Dominion are inclusive of Virginia Power and/or Dominion Gas, where applicable.

Note 3. Acquisitions and Dispositions

Dominion

Proposed Acquisition of Questar

Pursuant to the terms of the Questar Combination announced in February 2016, upon closing, each share of Questar common stock issued and outstanding immediately prior to the closing will be converted automatically into the right to receive $25 in cash per share, or approximately $4.4 billion in total. In addition, Questar’s debt, which currently totals approximately $1.5 billion is expected to remain outstanding. Dominion entered into agreements with several of its lending banks pursuant to

22

which they have unfunded financing commitments to provide a $3.9 billion acquisition facility. In connection with receipt of proceeds from Dominion’s issuance of common stock, the acquisition facility was reduced from $3.9 billion to $3.14 billion in April 2016. See Note 14 for more information. At June 30, 2016, $500 million of such proceeds are included in restricted cash and cash equivalents in Dominion’s Consolidated Balance Sheets. Dominion intends to permanently finance the transaction in a manner that supports its existing credit ratings targets by issuing a combination of common stock, mandatory convertibles and debt at Dominion, and indirectly through the issuance of securities at Dominion Midstream, the proceeds of which will be applied to pay Dominion for certain assets of Questar, which are, subject to relevant approvals, expected to be contributed to Dominion Midstream.

The transaction requires approval of Questar’s shareholders and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. In February 2016, the Federal Trade Commission granted antitrust approval of the Questar Combination under the Hart-Scott-Rodino Act. In March 2016, Questar and Dominion filed for review and approval, as required, from the Utah Public Service Commission and the Wyoming Public Service Commission, and provided information regarding the transaction to the Idaho Public Utilities Commission. In May 2016, Questar’s shareholders voted to approve the Questar Combination. The Questar Combination contains certain termination rights for both Dominion and Questar, and provides that, upon termination of the Questar Combination under specified circumstances, Dominion would be required to pay a termination fee of $154 million to Questar and Questar would be required to pay Dominion a termination fee of $99 million. Subject to any remaining required regulatory approvals and meeting closing conditions, Dominion targets closing by the end of 2016.

Non-Wholly-Owned Merchant Solar Projects

Acquisitions of Four Brothers and Three Cedars

In June 2015, Dominion acquired 50% of the units in Four Brothers from SunEdison for $64 million of consideration, consisting of $2 million in cash and a $62 million payable. As of June 30, 2016, an $11 million payable is included in other current liabilities in Dominion’s Consolidated Balance Sheets. Four Brothers’ purpose is to develop and operate four solar projects located in Utah, which will produce and sell electricity and renewable energy credits. The projects are expected to cost approximately $730 million to construct, including the initial acquisition cost. Dominion is obligated to contribute $445 million of capital to fund the construction of the projects and has contributed $370 million through June 30, 2016. The facilities are expected to begin commercial operations by the end of the third quarter of 2016, with generating capacity of approximately 320 MW.

In September 2015, Dominion acquired 50% of the units in Three Cedars from SunEdison for $43 million of consideration, consisting of $6 million in cash and a $37 million payable. As of June 30, 2016, a $7 million payable is included in other current liabilities in Dominion’s Consolidated Balance Sheets. Three Cedars’ purpose is to develop and operate three solar projects located in Utah, which will produce and sell electricity and renewable energy credits. The projects are expected to cost approximately $425 million to construct. Dominion is obligated to contribute $276 million of capital to fund the construction of the projects and has contributed $223 million through June 30, 2016. The facilities are expected to begin commercial operations by the end of the third quarter of 2016, with generating capacity of approximately 210 MW.

Long-term power purchase, interconnection and operation and maintenance agreements have been executed for both Four Brothers and Three Cedars. Dominion expects to claim 99% of the federal investment tax credits on the projects.

Dominion owns 50% of the voting interests in Four Brothers and Three Cedars and has a controlling financial interest over the entities through its rights to control operations. The allocation of the $64 million purchase price for Four Brothers resulted in $89 million of property, plant and equipment and $25 million of noncontrolling interest. The allocation of the $43 million purchase price for Three Cedars resulted in $65 million of property, plant and equipment and $22 million of noncontrolling interest. The noncontrolling interest for each entity was measured at fair value using the discounted cash flow method, with the primary components of the valuation being future cash flows (both incoming and outgoing) and the discount rate. Dominion determined its discount rate based on the cost of capital a utility-scale investor would expect, as well as the cost of capital an individual project developer could achieve via a combination of non-recourse project financing and outside equity partners. The acquired assets of Four Brothers and Three Cedars are included in the Dominion Generation operating segment.

Dominion has assumed the majority of the agreements to provide administrative and support services in connection with construction of the projects, operations and maintenance of the facilities and technical management services of the solar facilities. Costs related to services to be provided under these agreements were immaterial for the six months ended June 30, 2016. Subsequent to Dominion’s acquisition of Four Brothers and Three Cedars through June 30, 2016, SunEdison made contributions to Four Brothers and Three Cedars of $265 million in aggregate, which are reflected as noncontrolling interests in Dominion’s Consolidated Balance Sheets.

23

In April 2016, SunEdison filed for Chapter 11 bankruptcy; however, this is not expected to have a material adverse effect on Dominion, Four Brothers or Three Cedars.

Wholly-Owned Merchant Solar Projects

The following table presents significant completed acquisitions of wholly-owned merchant solar projects by Dominion in the second quarter of 2015. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for all of the projects. Dominion has claimed federal investment tax credits on the projects. These projects are included in the Dominion Generation operating segment.

Completed Acquisition Date	Seller	Number of Projects	Project Location	Project Name(s)	Initial Acquisition Cost (millions)(1)		Project Cost (millions)(2)		Date of Commercial Operations	MW Capacity
April 2015	EC&R NA Solar PV, LLC	1	California	Alamo	$	66	$	66	May 2015		20
April 2015	EDF Renewable Development, Inc.	3	California	Cottonwood(3)		106		106	May 2015		24
June 2015	EDF Renewable Development, Inc.	1	California	Catalina 2		68		68	July 2015		18

(1) The purchase price was primarily allocated to Property, Plant and Equipment.

(2) Includes acquisition cost.

(3) One of the projects, Marin Carport, began commercial operations in 2016.

Sale of Interest in Merchant Solar Projects

In September 2015, Dominion signed an agreement to sell a noncontrolling interest (consisting of 33% of the equity interests) in all of its then currently wholly-owned merchant solar projects, 24 solar projects totaling approximately 425 MW, to SunEdison, including projects discussed in the table above. In December 2015, the sale of interest in 15 of the solar projects closed for $184 million with the sale of interest in the remaining projects completed in January 2016 for $117 million. Upon closing, SunEdison sold its interest in these projects to Terra Nova Renewable Partners. Terra Nova Renewable Partners has a future option to buy all or a portion of Dominion’s remaining 67% ownership in the projects upon the occurrence of certain events, none of which had occurred as of June 30, 2016 nor are expected to occur in the remainder of 2016.

Acquisition of DCG

In January 2015, Dominion completed the acquisition of 100% of the equity interests of DCG from SCANA Corporation for $497 million in cash, as adjusted for working capital. DCG owns and operates nearly 1,500 miles of FERC-regulated interstate natural gas pipeline in South Carolina and southeastern Georgia. This acquisition supports Dominion’s natural gas expansion into the Southeast. The allocation of the purchase price resulted in $277 million of net property, plant and equipment, $250 million of goodwill, of which approximately $225 million is expected to be deductible for income tax purposes, and $38 million of regulatory liabilities. The goodwill reflects the value associated with enhancing Dominion’s regulated gas position, economic value attributable to future expansion projects as well as increased opportunities for synergies. The acquired assets of DCG are included in the Dominion Energy operating segment.

On March 24, 2015, DCG converted to a limited liability company under the laws of South Carolina and changed its name from Carolina Gas Transmission Corporation to DCG. On April 1, 2015, Dominion contributed 100% of the issued and outstanding membership interests of DCG to Dominion Midstream in exchange for total consideration of $501 million, as adjusted for working capital. Total consideration to Dominion consisted of the issuance of a two-year, $301 million senior unsecured promissory note payable by Dominion Midstream at an annual interest rate of 0.6%, and 5,112,139 common units, valued at $200 million, representing limited partner interests in Dominion Midstream. The number of units was based on the volume weighted average trading price of Dominion Midstream’s common units for the ten trading days prior to April 1, 2015, or $39.12 per unit. Since Dominion consolidates Dominion Midstream for financial reporting purposes, this transaction was eliminated upon consolidation and did not impact Dominion’s financial position or cash flows.

Dominion Gas

Assignments of Shale Development Rights

In December 2013, Dominion Gas closed an agreement with a natural gas producer to convey over time approximately 79,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields. The agreement provided for payments to Dominion Gas, subject to customary adjustments, of up to approximately $200 million over a period of nine years, and an overriding royalty interest in gas produced from the acreage. In March 2015, Dominion Gas and the natural gas

24

producer closed on an amendment to the agreement, which included the immediate conveyance of approximately 9,000 acres of Marcellus Shale development rights and a two year extension of the term of the original agreement. The conveyance of development rights resulted in the recognition of $43 million ($27 million after-tax) of previously deferred revenue to operations and maintenance expense in Dominion Gas’ Consolidated Statements of Income. In April 2016, Dominion Gas and the natural gas producer closed on an amendment to the agreement, which included the immediate conveyance of a 32% partial interest in the remaining approximately 70,000 acres. This conveyance resulted in the recognition of the remaining $35 million ($21 million after-tax) of previously deferred revenue to operations and maintenance expense in Dominion Gas’ Consolidated Statements of Income.

In March 2015, Dominion Gas conveyed to a natural gas producer approximately 11,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields and received proceeds of $27 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $27 million ($16 million after-tax) gain, included in other operations and maintenance expense in Dominion Gas’ Consolidated Statements of Income.

In November 2014, Dominion Gas closed on 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 connection with that agreement, in January 2016, Dominion Gas conveyed approximately 2,000 acres of Marcellus Shale development rights and received proceeds of $5 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $5 million ($3 million after-tax) gain, included in other operations and maintenance expense in Dominion Gas’ Consolidated Statements of Income. Also in connection with that agreement, in July 2016, Dominion Gas conveyed to a natural gas producer approximately 2,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields and received proceeds of $5 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $5 million ($3 million after-tax) gain.

Note 4. Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Dominion
Electric sales:
Regulated	$	1,718	$	1,779	$	3,560	$	3,891
Nonregulated		335		351		724		757
Gas sales:
Regulated		26		31		91		147
Nonregulated		54		87		172		295
Gas transportation and storage		369		385		784		856
Other		96		114		188		210
Total operating revenue	$	2,598	$	2,747	$	5,519	$	6,156
Virginia Power
Regulated electric sales	$	1,718	$	1,779	$	3,560	$	3,891
Other		58		34		106		59
Total operating revenue	$	1,776	$	1,813	$	3,666	$	3,950
Dominion Gas
Gas sales:
Regulated	$	12	$	21	$	41	$	78
Nonregulated		6		1		7		4
Gas transportation and storage		301		321		652		733
NGL revenue		9		22		26		51
Other		40		30		73		60
Total operating revenue	$	368	$	395	$	799	$	926

25

Note 5. Income Taxes

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

	Dominion						Virginia Power						Dominion Gas
Six Months Ended June 30,	2016			2015			2016			2015			2016			2015
United States statutory rate		35.0	%		35.0	%		35.0	%		35.0	%		35.0	%		35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit		4.3			3.3			4.0			3.8			3.8			3.9
Investment tax credits		(9.9	)		(2.7	)		—			—			—			—
Production tax credits		(0.8	)		(0.8	)		(0.6	)		(0.5	)		—			—
State legislative change		(1.3	)		—			—			—			—			—
Other, net		(2.3	)		(1.0	)		(0.5	)		(0.7	)		(0.1	)		—
Effective tax rate		25.0	%		33.8	%		37.9	%		37.6	%		38.7	%		38.9	%

As of June 30, 2016, 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, 2015 for a discussion of these unrecognized tax benefits.

Note 6. Earnings Per Share

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions, except EPS)
Net income attributable to Dominion	$	452	$	413	$	976	$	949
Average shares of common stock outstanding – Basic		615.6		591.5		606.1		589.7
Net effect of dilutive securities(1)		1.4		1.0		1.5		1.5
Average shares of common stock outstanding – Diluted		617.0		592.5		607.6		591.2
Earnings Per Common Share – Basic	$	0.73	$	0.70	$	1.61	$	1.61
Earnings Per Common Share – Diluted	$	0.73	$	0.70	$	1.61	$	1.60

(1) Dilutive securities consist primarily of the 2013 Equity Units. See Note 14 in this report and Note 17 to the Consolidated Financial Statements in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2015 for more information.

The 2014 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three and six months ended June 30, 2016 and 2015, as the dilutive stock price threshold was not met.

26

Note 7. Accumulated Other Comprehensive Income

Dominion

The following table presents Dominion’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 Income (Loss) From Equity Method Investee			Total
(millions)
Three Months Ended June 30, 2016
Beginning balance	$	(186	)	$	517		$	(789	)	$	(5	)	$	(463	)
Other comprehensive income before reclassifications: gains (losses)		(11	)		26			—			(1	)		14
Amounts reclassified from AOCI(1): (gains) losses		(44	)		(8	)		8			—			(44	)
Net current-period other comprehensive income (loss)		(55	)		18			8			(1	)		(30	)
Ending balance	$	(241	)	$	535		$	(781	)	$	(6	)	$	(493	)
Three Months Ended June 30, 2015
Beginning balance	$	(177	)	$	542		$	(769	)	$	(5	)	$	(409	)
Other comprehensive income before reclassifications: gains (losses)		92			(11	)		3			—			84
Amounts reclassified from AOCI(1): (gains) losses		(61	)		(12	)		12			—			(61	)
Net current-period other comprehensive income (loss)		31			(23	)		15			—			23
Ending balance	$	(146	)	$	519		$	(754	)	$	(5	)	$	(386	)
Six Months Ended June 30, 2016
Beginning balance	$	(176	)	$	504		$	(797	)	$	(5	)	$	(474	)
Other comprehensive income before reclassifications: gains (losses)		42			41			—			(1	)		82
Amounts reclassified from AOCI(1): (gains) losses		(107	)		(10	)		16			—			(101	)
Net current-period other comprehensive income (loss)		(65	)		31			16			(1	)		(19	)
Ending balance	$	(241	)	$	535		$	(781	)	$	(6	)	$	(493	)
Six Months Ended June 30, 2015
Beginning balance	$	(178	)	$	548		$	(782	)	$	(4	)	$	(416	)
Other comprehensive income before reclassifications: gains (losses)		34			4			3			(1	)		40
Amounts reclassified from AOCI(1): (gains) losses		(2	)		(33	)		25			—			(10	)
Net current-period other comprehensive income (loss)		32			(29	)		28			(1	)		30
Ending balance	$	(146	)	$	519		$	(754	)	$	(5	)	$	(386	)

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

The following table presents Dominion’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, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(87	)	Operating revenue
		2		Purchased gas
		3		Electric fuel and other energy-related purchases
Interest rate contracts		8		Interest and related charges
Foreign currency contracts		2		Other income
		(72	)
Tax		28		Income tax expense
	$	(44	)

27

Details About AOCI Components	Amounts Reclassified From AOCI			Affected Line Item in the Consolidated Statements of Income
(millions)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(20	)	Other income
Impairment		7		Other income
		(13	)
Tax		5		Income tax expense
	$	(8	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(3	)	Other operations and maintenance
Actuarial (gains) losses		17		Other operations and maintenance
		14
Tax		(6	)	Income tax expense
	$	8
Three Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(107	)	Operating revenue
		2		Purchased gas
Interest rate contracts		3		Interest and related charges
		(102	)
Tax		41		Income tax expense
	$	(61	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(25	)	Other income
Impairment		5		Other income
		(20	)
Tax		8		Income tax expense
	$	(12	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(3	)	Other operations and maintenance
Actuarial (gains) losses		24		Other operations and maintenance
		21
Tax		(9	)	Income tax expense
	$	12
Six Months Ended June 30, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(201	)	Operating revenue
		8		Purchased gas
		6		Electric fuel and other energy-related purchases
Interest rate contracts		11		Interest and related charges
Foreign currency contracts		2		Other income
		(174	)
Tax		67		Income tax expense
	$	(107	)

28

Details About AOCI Components	Amounts Reclassified From AOCI			Affected Line Item in the Consolidated Statements of Income
(millions)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(30	)	Other income
Impairment		14		Other income
		(16	)
Tax		6		Income tax expense
	$	(10	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(7	)	Other operations and maintenance
Actuarial (gains) losses		35		Other operations and maintenance
		28
Tax		(12	)	Income tax expense
	$	16
Six Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(15	)	Operating revenue
		7		Purchased gas
		(1	)	Electric fuel and other energy-related purchases
Interest rate contracts		5		Interest and related charges
		(4	)
Tax		2		Income tax expense
	$	(2	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(64	)	Other income
Impairment		11		Other income
		(53	)
Tax		20		Income tax expense
	$	(33	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(6	)	Other operations and maintenance
Actuarial (gains) losses		49		Other operations and maintenance
		43
Tax		(18	)	Income tax expense
	$	25

29

Dominion Gas

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

	Deferred Gains and Losses on Derivatives- Hedging Activities			Unrecognized Pension and Other Postretirement Benefit Costs			Total
(millions)
Three Months Ended June 30, 2016
Beginning balance	$	(25	)	$	(82	)	$	(107	)
Other comprehensive income before reclassifications: losses		(9	)		—			(9	)
Amounts reclassified from AOCI(1): losses		—			1			1
Net current-period other comprehensive income (loss)		(9	)		1			(8	)
Ending balance	$	(34	)	$	(81	)	$	(115	)
Three Months Ended June 30, 2015
Beginning balance	$	(24	)	$	(65	)	$	(89	)
Other comprehensive income before reclassifications: gains		3			—			3
Amounts reclassified from AOCI(1): (gains) losses		(1	)		1			—
Net current-period other comprehensive income		2			1			3
Ending balance	$	(22	)	$	(64	)	$	(86	)
Six Months Ended June 30, 2016
Beginning balance	$	(17	)	$	(82	)	$	(99	)
Other comprehensive income before reclassifications: losses		(15	)		—			(15	)
Amounts reclassified from AOCI(1): (gains) losses		(2	)		1			(1	)
Net current-period other comprehensive income (loss)		(17	)		1			(16	)
Ending balance	$	(34	)	$	(81	)	$	(115	)
Six Months Ended June 30, 2015
Beginning balance	$	(20	)	$	(66	)	$	(86	)
Other comprehensive income before reclassifications: losses		(1	)		—			(1	)
Amounts reclassified from AOCI(1): (gains) losses		(1	)		2			1
Net current-period other comprehensive income (loss)		(2	)		2			—
Ending balance	$	(22	)	$	(64	)	$	(86	)

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

30

The following table presents Dominion 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, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Foreign currency contracts	$	2		Other income
		2
Tax		(2	)	Income tax expense
	$	—
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	1		Other operations and maintenance
		1
Tax		—		Income tax expense
	$	1
Three Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
		(1	)
Tax		—		Income tax expense
	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	2		Other operations and maintenance
		2
Tax		(1	)	Income tax expense
	$	1
Six Months Ended June 30, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(4	)	Operating revenue
Foreign currency contracts		2		Other income
		(2	)
Tax		—		Income tax expense
	$	(2	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	2		Other operations and maintenance
		2
Tax		(1	)	Income tax expense
	$	1
Six Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
		(1	)
Tax		—		Income tax expense
	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	4		Other operations and maintenance
		4
Tax		(2	)	Income tax expense
	$	2

31

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, 2015. See Note 9 in this report for further information about the Companies’ derivatives and hedge accounting activities.

Dominion and Dominion Gas apply fair value measurements to foreign currency swaps used to manage the foreign currency exchange rate risk related to interest and principal payments denominated in foreign currencies. These swaps are designated as cash flow hedges for accounting purposes and are categorized as Level 2.

The inputs and assumptions used in measuring the fair value for foreign currency swaps include the following:

• Foreign currency forward exchange rates

• Credit quality of counterparties and the Companies

• Notional value

• Credit enhancements

• Time value

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 and futures contracts. An option model is used to value Level 3 physical and financial options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The 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, forward market prices, credit spreads 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’s quantitative information about Level 3 fair value measurements at June 30, 2016. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads and price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input	Range			Weighted Average(1)
Assets
Physical and financial forwards and futures:
Natural gas(2)	$	123	Discounted cash flow	Market price (per Dth)(3)		(2) - 7			—
				Credit spread(4)		1% - 6	%		3	%
FTRs		6	Discounted cash flow	Market price (per MWh)(3)		(8) - 3			1
Physical and financial options:
Natural gas		8	Option model	Market price (per Dth)(3)		2 - 7			4
				Price volatility(5)		20% - 42	%		25	%
Total assets	$	137
Liabilities
Physical and financial forwards and futures:
Natural gas(2)	$	5	Discounted cash flow	Market price (per Dth)(3)		(1) - 4			3
FTRs		7	Discounted cash flow	Market price (per MWh)(3)		(2) - 5			1
Physical and financial options:
Natural gas		1	Option model	Market price (per Dth)(3)		2 - 4			3
				Price volatility(5)		29% - 42	%		36	%
Total liabilities	$	13

32

(1) Averages weighted by volume.

(2) Includes basis.

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

(4) Represents credit spreads unrepresented in published markets.

(5) Represents volatilities unrepresented in published markets.

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

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

Recurring Fair Value Measurements

Dominion

The following table presents Dominion’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, 2016
Assets
Derivatives:
Commodity	$	—	$	192	$	137	$	329
Interest rate		—		25		—		25
Investments(1):
Equity securities:
United States:
Large cap		2,617		—		—		2,617
Other		5		—		—		5
REIT		72		—		—		72
Non-United States:
Large cap		10		—		—		10
Fixed income:
Corporate debt instruments		—		498		—		498
United States Treasury securities and agency debentures		462		236		—		698
State and municipal		—		364		—		364
Other		—		112		—		112
Cash equivalents and other		5		—		—		5
Total assets	$	3,171	$	1,427	$	137	$	4,735
Liabilities
Derivatives:
Commodity	$	—	$	87	$	13	$	100
Interest rate		—		366		—		366
Foreign currency		—		7		—		7
Total liabilities	$	—	$	460	$	13	$	473

33

	Level 1		Level 2		Level 3		Total
(millions)
At December 31, 2015
Assets
Derivatives:
Commodity	$	1	$	249	$	114	$	364
Interest rate		—		24		—		24
Investments(1):
Equity securities:
United States:
Large cap		2,547		—		—		2,547
Other		5		—		—		5
REIT		63		—		—		63
Non-United States:
Large cap		10		—		—		10
Fixed income:
Corporate debt instruments		—		437		—		437
United States Treasury securities and agency debentures		458		201		—		659
State and municipal		—		376		—		376
Other		—		100		—		100
Cash equivalents and other		2		2		—		4
Total assets	$	3,086	$	1,389	$	114	$	4,589
Liabilities
Derivatives:
Commodity	$	—	$	141	$	19	$	160
Interest rate		—		183		—		183
Total liabilities	$	—	$	324	$	19	$	343

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Beginning balance	$	109		$	76		$	95		$	107
Total realized and unrealized gains (losses):
Included in earnings		(10	)		(5	)		(17	)		10
Included in other comprehensive income (loss)		—			(1	)		3			(12	)
Included in regulatory assets/liabilities		15			(5	)		32			(29	)
Settlements		10			6			18			(8	)
Transfers out of Level 3		—			—			(7	)		3
Ending balance	$	124		$	71		$	124		$	71

The following table presents Dominion’s classification of gains and losses included in earnings in the Level 3 fair value category. 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 months ended June 30, 2016 and 2015.

34

	Operating Revenue		Electric Fuel and Other Energy- Related Purchases			Total
(millions)
Three Months Ended June 30, 2016
Total gains (losses) included in earnings	$	—	$	(10	)	$	(10	)
Three Months Ended June 30, 2015
Total gains (losses) included in earnings	$	—	$	(5	)	$	(5	)
Six Months Ended June 30, 2016
Total gains (losses) included in earnings	$	—	$	(17	)	$	(17	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date		—		—			—
Six Months Ended June 30, 2015
Total gains (losses) included in earnings	$	2	$	8		$	10
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date		1		(1	)		—

Virginia Power

The following table presents Virginia Power’s quantitative information about Level 3 fair value measurements at June 30, 2016. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads and price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input	Range			Weighted Average(1)
Assets
Physical and financial forwards and futures:
Natural gas(2)	$	121	Discounted cash flow	Market price (per Dth)(3)		(2) - 7			—
				Credit spread(4)		1% - 6	%		3	%
FTRs		6	Discounted cash flow	Market price (per MWh)(3)		(8) - 3			1
Physical and financial options:
Natural gas		5	Option model	Market price (per Dth)(3)		2 - 7			4
				Price volatility(5)		20% - 33	%		24	%
Total assets	$	132
Liabilities
Physical and financial forwards and futures:
FTRs	$	7	Discounted cash flow	Market price (per MWh)(3)		(2) - 5			1
Total liabilities	$	7

(1) Averages weighted by volume.

(2) Includes basis.

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

(4) Represents credit spreads unrepresented in published markets.

(5) Represents volatilities unrepresented in published markets.

35

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

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

36

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, 2016
Assets
Derivatives:
Commodity	$	—	$	31	$	132	$	163
Investments(1):
Equity securities:
United States large cap		1,137		—		—		1,137
REIT		72		—		—		72
Fixed income:
Corporate debt instruments		—		283		—		283
United States Treasury securities and agency debentures		166		111		—		277
State and municipal		—		159		—		159
Other		—		48		—		48
Total assets	$	1,375	$	632	$	132	$	2,139
Liabilities
Derivatives:
Commodity	$	—	$	10	$	7	$	17
Interest rate		—		257		—		257
Total liabilities	$	—	$	267	$	7	$	274
At December 31, 2015
Assets
Derivatives:
Commodity	$	—	$	13	$	101	$	114
Interest rate		—		13		—		13
Investments(1):
Equity securities:
United States large cap		1,100		—		—		1,100
REIT		63		—		—		63
Fixed income:
Corporate debt instruments		—		238		—		238
United States Treasury securities and agency debentures		180		79		—		259
State and municipal		—		175		—		175
Other		—		34		—		34
Total assets	$	1,343	$	552	$	101	$	1,996
Liabilities
Derivatives:
Commodity	$	—	$	19	$	8	$	27
Interest rate		—		59		—		59
Total liabilities	$	—	$	78	$	8	$	86

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

37

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 June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Beginning balance	$	110		$	78		$	93		$	102
Total realized and unrealized gains (losses):
Included in earnings		(9	)		(5	)		(17	)		8
Included in regulatory assets/liabilities		15			(5	)		32			(29	)
Settlements		9			5			17			(8	)
Ending balance	$	125		$	73		$	125		$	73

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, 2016 and 2015. 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, 2016 and 2015.

Dominion Gas

The following table presents Dominion 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, 2016
Assets
Commodity	$	—	$	3	$	—	$	3
Total Assets	$	—	$	3	$	—	$	3
Liabilities
Commodity	$	—	$	5	$	—	$	5
Foreign currency		—		7		—		7
Total liabilities	$	—	$	12	$	—	$	12
At December 31, 2015
Assets
Commodity	$	—	$	5	$	6	$	11
Total Assets	$	—	$	5	$	6	$	11
Liabilities
Interest rate	$	—	$	14	$	—	$	14
Total liabilities	$	—	$	14	$	—	$	14

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

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016			2015
(millions)
Beginning balance	$	—	$	—		$	6		$	2
Total realized and unrealized gains (losses):
Included in earnings		—		(1	)		—			1
Included in other comprehensive income (loss)		—		—			2			(12	)
Settlements		—		—			—			(1	)
Transfers out of Level 3		—		—			(8	)		9
Ending balance	$	—	$	(1	)	$	—		$	(1	)

38

The gains and losses included in earnings in the Level 3 fair value category were classified in operating revenue in Dominion Gas’ Consolidated Statements of Income for the three and six months ended June 30, 2015. 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, 2016 and 2015.

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 cash equivalents, customer and other 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, 2016				December 31, 2015
	Carrying     Amount		Estimated Fair     Value(1)		Carrying     Amount		Estimated Fair     Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	22,754	$	25,400	$	21,873	$	23,210
Junior subordinated notes(3)		2,399		2,310		1,340		1,192
Remarketable subordinated notes(3)		982		1,037		2,080		2,129
Virginia Power
Long-term debt, including securities due within one year(3)	$	9,661	$	11,329	$	9,368	$	10,400
Dominion Gas
Long-term debt, including securities due within one year(4)	$	3,941	$	4,116	$	3,269	$	3,299

(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 and/or premium, and foreign currency remeasurement adjustments. At June 30, 2016 and December 31, 2015, includes the valuation of certain fair value hedges associated with fixed rate debt of $21 million and $7 million, respectively.

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

(4) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount and/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, 2015. 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’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. Dominion Gas’ and Virginia Power’s derivative contracts consist of over-the-counter transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a counterparty. 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.

39

Dominion

Balance Sheet Presentation

The tables below present Dominion’s derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:

	June 30, 2016						December 31, 2015
	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	$	231	$	—	$	231	$	217	$	—	$	217
Exchange		91		—		91		138		—		138
Interest rate contracts:
Over-the-counter		25		—		25		24		—		24
Total derivatives, subject to a master netting or similar arrangement		347		—		347		379		—		379
Total derivatives, not subject to a master netting or similar arrangement		7		—		7		9		—		9
Total	$	354	$	—	$	354	$	388	$	—	$	388

			June 30, 2016								December 31, 2015
			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	$	231	$	16	$	—	$	215	$	217	$	37	$	—	$	180
Exchange		91		63		—		28		138		82		—		56
Interest rate contracts:
Over-the-counter		25		15		—		10		24		22		—		2
Total	$	347	$	94	$	—	$	253	$	379	$	141	$	—	$	238

40

	June 30, 2016						December 31, 2015
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	32	$	—	$	32	$	70	$	—	$	70
Exchange		63		—		63		82		—		82
Interest rate contracts:
Over-the-counter		366		—		366		183		—		183
Foreign currency contracts:
Over-the-counter		7		—		7		—		—		—
Total derivatives, subject to a master netting or similar arrangement		468		—		468		335		—		335
Total derivatives, not subject to a master netting or similar arrangement		5		—		5		8		—		8
Total	$	473	$	—	$	473	$	343	$	—	$	343

			June 30, 2016								December 31, 2015
			Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Commodity contracts:
Over-the-counter	$	32	$	16	$	1	$	15	$	70	$	37	$	—	$	33
Exchange		63		63		—		—		82		82		—		—
Interest rate contracts:
Over-the-counter		366		15		—		351		183		22		—		161
Foreign currency contracts:
Over-the-counter		7		—		—		7		—		—		—		—
Total	$	468	$	94	$	1	$	373	$	335	$	141	$	—	$	194

Volumes

The following table presents the volume of Dominion’s derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

41

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)		125		38
Basis		190		580
Electricity (MWh):
Fixed price		11,749,639		1,978,640
FTRs		99,882,813		—
Liquids (Gal)(2)		59,807,554		—
Interest rate(3)	$	2,400,000,000	$	2,100,000,000
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, 2016 and 2015, 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 gains or losses attributable to changes in the time value of options and 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’s Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	10		$	9			22 months
Electricity		65			65			18 months
Other		(1	)		(1	)		9 months
Interest rate		(312	)		(23	)		381 months
Foreign currency		(3	)		(3	)		120 months
Total	$	(241	)	$	47

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.

42

Fair Value and Gains and Losses on Derivative Instruments

The following table presents the fair values of Dominion’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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	67	$	121	$	188
Interest rate		4		—		4
Total current derivative assets(1)		71		121		192
Noncurrent Assets
Commodity		6		135		141
Interest rate		21		—		21
Total noncurrent derivative assets(2)		27		135		162
Total derivative assets	$	98	$	256	$	354
LIABILITIES
Current Liabilities
Commodity	$	27	$	61	$	88
Interest rate		178		—		178
Foreign currency		5		—		5
Total current derivative liabilities(3)		210		61		271
Noncurrent Liabilities
Commodity		5		7		12
Interest rate		188		—		188
Foreign currency		2		—		2
Total noncurrent derivative liabilities(4)		195		7		202
Total derivative liabilities	$	405	$	68	$	473
At December 31, 2015
ASSETS
Current Assets
Commodity	$	101	$	151	$	252
Interest rate		3		—		3
Total current derivative assets(1)		104		151		255
Noncurrent Assets
Commodity		3		109		112
Interest rate		21		—		21
Total noncurrent derivative assets(2)		24		109		133
Total derivative assets	$	128	$	260	$	388
LIABILITIES
Current Liabilities
Commodity	$	32	$	116	$	148
Interest rate		164		—		164
Total current derivative liabilities(3)		196		116		312
Noncurrent Liabilities
Commodity		—		12		12
Interest rate		19		—		19
Total noncurrent derivative liabilities(4)		19		12		31
Total derivative liabilities	$	215	$	128	$	343

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

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

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

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

43

The following tables present the gains and losses on Dominion’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, 2016
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	87
Purchased gas					(2	)
Electric fuel and other energy-related purchases					(3	)
Total commodity	$	12		$	82		$	—
Interest rate(3)		(23	)		(8	)		(108	)
Foreign currency(4)		(7	)		(2	)		—
Total	$	(18	)	$	72		$	(108	)
Three Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	107
Purchased gas					(2	)
Total commodity	$	94		$	105		$	—
Interest rate(3)		57			(3	)		(91	)
Total	$	151		$	102		$	(91	)
Six Months Ended June 30, 2016
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	201
Purchased gas					(8	)
Electric fuel and other energy-related purchases					(6	)
Total commodity	$	185		$	187		$	—
Interest rate(3)		(110	)		(11	)		(241	)
Foreign currency(4)		(7	)		(2	)		—
Total	$	68		$	174		$	(241	)
Six Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	15
Purchased gas					(7	)
Electric fuel and other energy-related purchases					1
Total commodity	$	54		$	9		$	3
Interest rate(3)		(1	)		(5	)		42
Total	$	53		$	4		$	45

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

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

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

44

	Amount of Gain (Loss) Recognized in Income on  Derivatives(1)
	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015			2016			2015
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	(8	)	$	15		$	(6	)	$	18
Purchased gas		8			(7	)		7			(9	)
Electric fuel and other energy-related purchases		(9	)		3			(31	)		9
Other operations and maintenance		1			—			—			—
Total	$	(8	)	$	11		$	(30	)	$	18

(1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion’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, 2016						December 31, 2015
	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	$	127	$	—	$	127	$	101	$	—	$	101
Interest rate contracts:
Over-the-counter		—		—		—		13		—		13
Total derivatives, subject to a master netting or similar arrangement		127		—		127		114		—		114
Total derivatives, not subject to a master netting or similar arrangement		36		—		36		13		—		13
Total	$	163	$	—	$	163	$	127	$	—	$	127

			June 30, 2016								December 31, 2015
			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	$	127	$	7	$	—	$	120	$	101	$	3	$	—	$	98
Interest rate contracts:
Over-the-counter		—		—		—		—		13		10		—		3
Total	$	127	$	7	$	—	$	120	$	114	$	13	$	—	$	101

45

	June 30, 2016						December 31, 2015
	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	$	14	$	—	$	14	$	5	$	—	$	5
Interest rate contracts:
Over-the-counter		257		—		257		59		—		59
Total derivatives, subject to a master netting or similar arrangement		271		—		271		64		—		64
Total derivatives, not subject to a master netting or similar arrangement		3		—		3		22		—		22
Total	$	274	$	—	$	274	$	86	$	—	$	86

			June 30, 2016								December 31, 2015
			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	$	14	$	7	$	1	$	6	$	5	$	3	$	—	$	2
Interest rate contracts:
Over-the-counter		257		—		—		257		59		10		—		49
Total	$	271	$	7	$	1	$	263	$	64	$	13	$	—	$	51

Volumes

The following table presents the volume of Virginia Power’s derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)		42		16
Basis		67		538
Electricity (MWh):
FTRs		97,710,646		—
Interest rate	$	700,000,000	$	1,100,000,000

(1) Includes options.

Ineffectiveness and AOCI

For the three and six months ended June 30, 2016 and 2015, gains or losses on hedging instruments determined to be ineffective were not material.

46

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(21	)	$	(1	)		381 months
Total	$	(21	)	$	(1	)

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 interest rates.

47

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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	—	$	34	$	34
Total current derivative assets(1)		—		34		34
Noncurrent Assets
Commodity		—		129		129
Total noncurrent derivative assets(2)		—		129		129
Total derivative assets	$	—	$	163	$	163
LIABILITIES
Current Liabilities
Commodity	$	—	$	12	$	12
Interest rate		69		—		69
Total current derivative liabilities(3)		69		12		81
Noncurrent Liabilities
Commodity		—		5		5
Interest rate		188		—		188
Total noncurrent derivatives liabilities (4)		188		5		193
Total derivative liabilities	$	257	$	17	$	274
At December 31, 2015
ASSETS
Current Assets
Commodity	$	—	$	18	$	18
Total current derivative assets(1)		—		18		18
Noncurrent Assets
Commodity		—		96		96
Interest rate		13		—		13
Total noncurrent derivative assets(2)		13		96		109
Total derivative assets	$	13	$	114	$	127
LIABILITIES
Current Liabilities
Commodity	$	—	$	23	$	23
Interest rate		57		—		57
Total current derivative liabilities(3)		57		23		80
Noncurrent Liabilities
Commodity		—		4		4
Interest rate		2		—		2
Total noncurrent derivative liabilities(4)		2		4		6
Total derivative liabilities	$	59	$	27	$	86

(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.

48

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, 2016
Derivative type and location of gains (losses):
Interest rate(3)	$	(10	)	$	—		$	(108	)
Total	$	(10	)	$	—		$	(108	)
Three Months Ended June 30, 2015
Derivative type and location of gains (losses):
Interest rate(3)	$	11		$	—		$	91
Total	$	11		$	—		$	91
Six Months Ended June 30, 2016
Derivative type and location of gains (losses):
Interest rate(3)	$	(24	)	$	(1	)	$	(241	)
Total	$	(24	)	$	(1	)	$	(241	)
Six Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Total commodity	$	—		$	(1	)	$	3
Interest rate(3)		5			—			42
Total	$	5		$	(1	)	$	45

(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.

	Amount of Gain (Loss) Recognized in Income on  Derivatives(1)
	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015		2016			2015
(millions)
Derivative type and location of gains (losses):
Commodity(2)	$	(10	)	$	5	$	(30	)	$	12
Total	$	(10	)	$	5	$	(30	)	$	12

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

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

49

Dominion Gas

Balance Sheet Presentation

The tables below present Dominion Gas’ derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting.

	June 30, 2016						December 31, 2015
	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	$	3	$	—	$	3	$	11	$	—	$	11
Total derivatives, subject to a master netting or similar arrangement	$	3	$	—	$	3	$	11	$	—	$	11

			June 30, 2016								December 31, 2015
			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	$	3	$	3	$	—	$	—	$	11	$	—	$	—	$	11
Total	$	3	$	3	$	—	$	—	$	11	$	—	$	—	$	11

	June 30, 2016						December 31, 2015
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	5	$	—	$	5	$	—	$	—	$	—
Interest rate contracts:
Over-the-counter		—		—		—		14		—		14
Foreign currency contracts:
Over-the-counter		7		—		7		—		—		—
Total derivatives, subject to a master netting or similar arrangement	$	12	$	—	$	12	$	14	$	—	$	14

50

			June 30, 2016								December 31, 2015
			Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Commodity contracts
Over-the-counter	$	5	$	3	$	—	$	2	$	—	$	—	$	—	$	—
Interest rate contracts:
Over-the-counter		—		—		—		—		14		—		—		14
Foreign currency contracts:
Over-the-counter		7		—		—		7		—		—		—		—
Total	$	12	$	3	$	—	$	9	$	14	$	—	$	—	$	14

Volumes

The following table presents the volume of Dominion Gas’ derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price		7		—
Basis		7		—
NGLs (Gal)		52,247,554		—
Foreign currency(1)	$	—	$	280,000,000

(1) Maturity is determined based on final settlement period. Euro equivalent volumes are €250,000,000.

Ineffectiveness and AOCI

For the three and six months ended June 30, 2016 and 2015, 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 Dominion Gas’ Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
NGLs	$	(1	)	$	(1	)		9 months
Interest rate		(30	)		(4	)		342 months
Foreign currency		(3	)		(3	)		120 months
Total	$	(34	)	$	(8	)

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 rates.

51

Fair Value and Gains and Losses on Derivative Instruments

The following tables present the fair values of Dominion 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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	2	$	1	$	3
Total current derivative assets(1)		2		1		3
Total derivative assets	$	2	$	1	$	3
LIABILITIES
Current Liabilities
Commodity	$	4	$	1	$	5
Foreign currency		5		—		5
Total current derivative liabilities(3)		9		1		10
Noncurrent Liabilities
Foreign currency		2		—		2
Total noncurrent derivative liabilities(4)		2		—		2
Total derivative liabilities	$	11	$	1	$	12
At December 31, 2015
ASSETS
Current Assets
Commodity	$	10	$	—	$	10
Total current derivative assets(1)		10		—		10
Noncurrent Assets
Commodity		1		—		1
Total noncurrent derivatives assets(2)		1		—		1
Total derivative assets	$	11	$	—	$	11
LIABILITIES
Noncurrent Liabilities
Interest rate	$	14	$	—	$	14
Total noncurrent derivative liabilities(4)		14		—		14
Total derivative liabilities	$	14	$	—	$	14

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

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

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

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

52

The following table presents the gains and losses on Dominion 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, 2016
Derivative Type and Location of Gains (Losses):
Commodity	$	(6	)	$	—
Foreign currency(3)		(7	)		(2	)
Total	$	(13	)	$	(2	)
Three Months Ended June 30, 2015
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	1
Total commodity	$	—		$	1
Interest rate(2)		4			—
Total	$	4		$	1
Six Months Ended June 30, 2016
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	4
Total commodity	$	(7	)	$	4
Interest rate(2)		(9	)		—
Foreign currency(3)		(7	)		(2	)
Total	$	(23	)	$	2
Six Months Ended June 30, 2015
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	1
Total commodity	$	(2	)	$	1
Total	$	(2	)	$	1

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

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

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

	Amount of Gain (Loss) Recognized in Income on Derivatives
	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015		2016			2015
(millions)
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue	$	(2	)	$	3	$	(2	)	$	4
Total	$	(2	)	$	3	$	(2	)	$	4

53

Note 10. Investments

Dominion

Equity and Debt Securities

Rabbi Trust Securities

Marketable equity and debt securities and cash equivalents held in Dominion’s rabbi trusts and classified as trading totaled $104 million and $100 million at June 30, 2016 and December 31, 2015, respectively.

Decommissioning Trust Securities

Dominion holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Dominion’s decommissioning trust funds are summarized below:

	Amortized Cost			Total Unrealized Gains(1)		Total Unrealized Losses(1)			Fair Value
(millions)
At June 30, 2016
Marketable equity securities:
United States large cap	$	1,326		$	1,251	$	—		$	2,577
REIT		61			11		—			72
Marketable debt securities:
Corporate bonds		474			25		(1	)		498
United States Treasury securities and agency debentures		672			26		—			698
State and municipal		290			31		—			321
Other		108			—		—			108
Cost method investments		69			—		—			69
Cash equivalents and other(2)		(12	)		—		—			(12	)
Total	$	2,988		$	1,344	$	(1	)(3)	$	4,331
At December 31, 2015
Marketable equity securities:
United States large cap	$	1,295		$	1,213	$	—		$	2,508
REIT		59			4		—			63
Marketable debt securities:
Corporate bonds		433			11		(7	)		437
United States Treasury securities and agency debentures		654			8		(4	)		658
State and municipal		312			22		—			334
Other		99			—		—			99
Cost method investments		70			—		—			70
Cash equivalents and other(2)		14			—		—			14
Total	$	2,936		$	1,258	$	(11	)(3)	$	4,183

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

(2) Includes pending purchases of securities of $16 million and pending sales of securities of $12 million at June 30, 2016 and December 31, 2015, respectively.

(3) The fair value of securities in an unrealized loss position was $90 million and $592 million at June 30, 2016 and December 31, 2015, respectively.

The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2016 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	212
Due after one year through five years		458
Due after five years through ten years		390
Due after ten years		565
Total	$	1,625

54

Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Proceeds from sales	$	341	$	243	$	709	$	580
Realized gains(1)		37		44		62		100
Realized losses(1)		15		12		34		29

(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 for Dominion were not material for the three and six months ended June 30, 2016 and 2015.

Virginia Power

Virginia Power holds marketable equity and debt securities (classified as available-for-sale), 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(1)		Total Unrealized Losses(1)			Fair Value
(millions)
At June 30, 2016
Marketable equity securities:
United States large cap	$	590		$	546	$	—		$	1,136
REIT		61			11		—			72
Marketable debt securities:
Corporate bonds		271			13		(1	)		283
United States Treasury securities and agency debentures		270			7		—			277
State and municipal		141			17		—			158
Other		48			—		—			48
Cost method investments		69			—		—			69
Cash equivalents and other(2)		(13	)		—		—			(13	)
Total	$	1,437		$	594	$	(1	)(3)	$	2,030
At December 31, 2015
Marketable equity securities:
United States large cap	$	574		$	525	$	—		$	1,099
REIT		59			4		—			63
Marketable debt securities:
Corporate bonds		237			5		(4	)		238
United States Treasury securities and agency debentures		260			1		(2	)		259
State and municipal		162			13		(1	)		174
Other		34			—		—			34
Cost method investments		70			—		—			70
Cash equivalents and other(2)		8			—		—			8
Total	$	1,404		$	548	$	(7	)(3)	$	1,945

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

(2) Includes pending purchases of securities of $13 million and pending sales of securities of $8 million at June 30, 2016 and December 31, 2015, respectively.

(3) The fair value of securities in an unrealized loss position was $66 million and $281 million at June 30, 2016 and December 31, 2015, respectively.

55

The fair value of Virginia Power’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2016 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	71
Due after one year through five years		207
Due after five years through ten years		218
Due after ten years		270
Total	$	766

Presented below is selected information regarding Virginia Power’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Proceeds from sales	$	154	$	76	$	347	$	209
Realized gains(1)		18		19		30		37
Realized losses(1)		7		4		17		15

(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 for Virginia Power were not material for the three and six months ended June 30, 2016 and 2015.

Equity Method Investments

Dominion Gas

Iroquois

Dominion Gas’ equity earnings totaled $9 million and $12 million for the six months ended June 30, 2016 and 2015, respectively. Dominion Gas received distributions from this investment of $11 million and $12 million for the six months ended June 30, 2016 and 2015, respectively. At June 30, 2016 and December 31, 2015, the carrying amount of Dominion Gas’ investment of $98 million and $102 million, respectively, exceeded its share of underlying equity in net assets by $8 million. The difference reflects equity method goodwill and is not being amortized. In May 2016, Dominion Gas sold 0.65% of the non-controlling partnership interest in Iroquois to TransCanada for approximately $7 million, which resulted in a $5 million ($3 million after-tax) gain.

Note 11. Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2016		December 31, 2015
(millions)
Dominion
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	95	$	90
Deferred nuclear refueling outage costs(2)		61		75
Deferred cost of fuel used in electric generation(3)		5		111
Other		60		75
Regulatory assets-current(4)		221		351
Unrecognized pension and other postretirement benefit costs(5)		992		1,015
Derivatives(6)		351		110
Deferred rate adjustment clause costs(1)		342		295
PJM transmission rates(7)		192		192
Income taxes recoverable through future rates(8)		137		126

56

	June 30, 2016		December 31, 2015
(millions)
Other		136		127
Regulatory assets-non-current		2,150		1,865
Total regulatory assets	$	2,371	$	2,216
Regulatory liabilities:
Deferred cost of fuel used in electric generation(3)	$	89	$	—
PIPP(9)		25		46
Other		47		54
Regulatory liabilities-current(10)		161		100
Provision for future cost of removal and AROs(11)		1,148		1,120
Nuclear decommissioning trust(12)		852		804
Derivatives(6)		108		79
Deferred cost of fuel used in electric generation(3)		26		97
Other		184		185
Regulatory liabilities-non-current		2,318		2,285
Total regulatory liabilities	$	2,479	$	2,385
Virginia Power
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	72	$	80
Deferred nuclear refueling outage costs(2)		61		75
Deferred cost of fuel used in electric generation(3)		5		111
Other		55		60
Regulatory assets-current		193		326
Derivatives(6)		351		110
Deferred rate adjustment clause costs(1)		254		213
PJM transmission rates(7)		192		192
Income taxes recoverable through future rates(8)		106		97
Other		63		55
Regulatory assets-non-current		966		667
Total regulatory assets	$	1,159	$	993
Regulatory liabilities:
Deferred cost of fuel used in electric generation(3)	$	89	$	—
Other		23		35
Regulatory liabilities-current(10)		112		35
Provision for future cost of removal(11)		913		890
Nuclear decommissioning trust(12)		852		804
Derivatives(6)		108		79
Deferred cost of fuel used in electric generation(3)		26		97
Other		57		59
Regulatory liabilities-non-current		1,956		1,929
Total regulatory liabilities	$	2,068	$	1,964
Dominion Gas
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	23	$	10
Other		2		13
Regulatory assets-current(4)		25		23
Unrecognized pension and other postretirement benefit costs(5)		277		282
Deferred rate adjustment clause costs(1)		88		82

57

	June 30, 2016		December 31, 2015
(millions)
Income taxes recoverable through future rates(8)		20		20
Other		66		65
Regulatory assets-non-current(13)		451		449
Total regulatory assets	$	476	$	472
Regulatory liabilities:
PIPP(9)	$	25	$	46
Other		18		9
Regulatory liabilities-current(10)		43		55
Provision for future cost of removal and AROs(11)		174		170
Other		39		31
Regulatory liabilities-non-current(14)		213		201
Total regulatory liabilities	$	256	$	256

(1) Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 12 for more information.

(2) 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.

(3) Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion’s and Virginia Power’s generation operations. See Note 12 for more information.

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

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

(6) 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.

(7) Reflects amounts related to PJM transmission cost allocation matter. See Note 12 for more information.

(8) Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.

(9) 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.

(10) Current regulatory liabilities are presented in other current liabilities in the Companies’ Consolidated Balance Sheets.

(11) 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.

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

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

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

At June 30, 2016, $293 million of Dominion’s, $272 million of Virginia Power’s and $18 million of Dominion Gas’ regulatory assets represented past expenditures on which they do not currently earn a return. These expenditures are expected to be recovered within the next two years.

Note 12. Regulatory Matters

Regulatory Matters Involving Potential Loss Contingencies

As a result of issues generated in the ordinary course of business, the Companies are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for the Companies to estimate a range of possible loss. For 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

58

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’s merchant generators sell electricity in the PJM, MISO, CAISO and ISO-NE wholesale markets, and to wholesale purchasers in the states of Tennessee, Georgia, California and Utah, under Dominion’s market-based sales tariffs authorized by FERC. 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. While Virginia Power cannot predict the outcome of the hearing, 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 United States 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 United States 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. Under the terms of the settlement, Virginia Power would be required to pay approximately $200 million to PJM over the next 10 years. Although the settlement agreement has not been accepted by FERC, and the settlement is opposed by a small group of parties to the

59

proceeding, Virginia Power believes it is probable it will be required to make payment as an outcome of the settlement. Accordingly, as of June 30, 2016, Virginia Power has recorded a contingent liability of $200 million in other deferred credits and other liabilities, which is offset by a $192 million regulatory asset for the amount that will be recovered through retail rates in Virginia. The remaining $8 million was recorded in other operations and maintenance expense in the Consolidated Statement of Income for the year ended December 31, 2015.

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, 2015 and Note 12 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2016.

Regulation Act Legislation

In February 2016, certain industrial customers of APCo petitioned the Virginia Commission to issue a declaratory judgment that Virginia legislation enacted in 2015 keeping APCo’s base rates unchanged until at least 2020 (and Virginia Power’s base rates unchanged until at least 2022) is unconstitutional, and to require APCo to make biennial review filings in 2016 and 2018. Virginia Power intervened to support the constitutionality of this legislation. In July 2016, the Virginia Commission held in a divided opinion that this legislation is constitutional, and the industrial customers appealed this order to the Supreme Court of Virginia. This appeal is pending.

2015 Biennial Review

In May 2016, the Supreme Court of Virginia denied the Attorney General’s unopposed motion to suspend briefing in the previously granted appeals from the Virginia Commission’s orders in Virginia Power’s 2015 biennial review case. The Supreme Court of Virginia later granted leave for the industrial customer appellants to withdraw their appeals, thus concluding this matter.

Virginia Fuel Expenses

In May 2016, the Virginia Commission ordered Virginia Power’s proposed fuel rate decrease to become effective July 1, 2016 on an interim basis. Virginia Power’s proposed fuel rate represents a fuel revenue decrease of $286 million when applied to projected kilowatt-hour sales for the period July 1, 2016 to June 30, 2017. This case is pending.

Solar Facility Projects

In October 2015, Virginia Power filed an application with the Virginia Commission for CPCNs to construct and operate the Scott Solar, Whitehouse, and Woodland solar facilities and related distribution-level interconnection facilities. Virginia Power also applied for approval of Rider US-2 to recover the costs of these projects, which would increase Dominion’s renewable generation by a combined 56 MW at an estimated cost of approximately $130 million, excluding financing costs. In June 2016, the Virginia Commission granted the requested CPCNs and approved a $4 million revenue requirement, subject to true-up on a cost of service basis using a 9.6% ROE for Rider US-2 for the rate year beginning September 1, 2016.

In August 2016, Virginia Power filed an application with the Virginia Commission for a CPCN to construct and operate the Oceana solar facility and related distribution interconnection facilities on land owned by the United States Navy. The facility would begin commercial operations in late 2017 and increase Dominion’s renewable generation by approximately 18 MW at an estimated cost of approximately $40 million, excluding financing costs. The facility is the subject of a public-private partnership whereby the Commonwealth of Virginia, a non-jurisdictional customer, will compensate Virginia Power for the facility’s net electrical energy output. Virginia Power will retire renewable energy certificates on the Commonwealth’s behalf in an amount equal to those generated by the facility. There is no rate adjustment clause associated with this CPCN filing, nor will any costs of the project be recovered from jurisdictional customers. This case is pending.

Rate Adjustment Clauses

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

• The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2016, Virginia Power proposed a $254 million revenue requirement for the rate year beginning April 1, 2017, which represents a $3 million increase over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider R in conjunction with Bear Garden. In June 2016, Virginia Power proposed a $75 million revenue requirement for the rate year beginning April 1, 2017, which represents a $1 million increase over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider W in conjunction with Warren County. In June 2016, Virginia Power proposed a $126 million revenue requirement for the rate year beginning April 1, 2017, which represents a $9 million increase over the previous year. This matter is pending.

60

• The Virginia Commission previously approved Rider B in conjunction with the conversion of three power stations to biomass. In June 2016, Virginia Power proposed a $28 million revenue requirement for the rate year beginning April 1, 2017, which represents a $1 million decrease over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider GV in conjunction with Greensville County. In June 2016, Virginia Power proposed a $89 million revenue requirement for the rate year beginning April 1, 2017, which represents a $49 million increase over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider BW in conjunction with Brunswick County. In June 2016, the Virginia Commission approved a $119 million revenue requirement for the rate year beginning September 1, 2016. It also established a 10.6% ROE for Rider BW effective September 1, 2016.

• The Virginia Commission previously approved Rider T1 concerning transmission rates. In May 2016, Virginia Power proposed a $639 million total revenue requirement for the rate year beginning September 1, 2016, which represents a $1 million increase over the revenues projected to be produced during the rate year under current rates. In July 2016, the Virginia Commission approved Virginia Power’s proposed total revenue requirement.

North Anna

Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna nuclear power station. If Virginia Power decides to build a new unit, it must first receive a COL from the NRC, approval of the Virginia Commission and certain environmental permits and other approvals. The COL is expected in 2017. Virginia Power has not yet committed to building a new nuclear unit at North Anna nuclear power station.

The motions and petitions filed by BREDL prior to April 2015 were dismissed, and under a previous ruling of the NRC, the contested portion of the COL proceeding remains terminated. The NRC is required to conduct a hearing in all COL proceedings, and if a new contention is not admitted, the mandatory NRC hearing will be uncontested.

In April 2015, BREDL filed a new motion and petition challenging the NRC’s reliance on its rule generically assessing the environmental impacts of continued onsite storage of spent nuclear fuel in licensing proceedings. The BREDL filings were substantially the same as those filed in other COL proceedings in which final environmental impact statements were issued prior to promulgation of the continued storage rule, like North Anna 3. In June 2015, the NRC denied the April 2015 motion and petition.

In August 2015, BREDL filed a petition in the United States Court of Appeals for the District of Columbia Circuit seeking review of the NRC’s June 2015 decision, and Virginia Power intervened. This petition and nine similar petitions relating to other NRC licensing proceedings were held in abeyance pending the outcome of the ongoing judicial review of the NRC’s continued storage rule before the same court. In June 2016, in New York v. NRC, the court upheld the NRC’s continued storage rule. In July 2016, the petitioners in New York v. NRC petitioned for rehearing en banc on their challenge to the continued storage rule, and the court ordered that BREDL’s August 2015 petition pertaining to the application of this rule to North Anna 3, and the similar petitions relating to other NRC proceedings, continue to be held in abeyance until the court’s disposition of the rehearing petition.

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 July 2016, East Ohio’s annual update of the PIPP Rider was automatically approved by the Ohio Commission after a 45 day waiting period from the date of the filing. The revised rider rate reflects the recovery over the twelve-month period from July 2016 through June 2017 of projected deferred program costs of approximately $32 million from April 2016 through June 2017, net of a refund for over-recovery of accumulated arrearages of approximately $28 million as of March 31, 2016.

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 2016, East Ohio filed an application with the Ohio Commission requesting approval to increase its UEX Rider to reflect a refund of over-recovered accumulated bad debt expense of approximately $8 million as of March 31, 2016, and recovery of prospective net bad debt expense projected to total approximately $19 million for the twelve-month period from April 2016 to March 2017. This case is pending.

61

West Virginia Regulation

In May 2016, Hope filed a PREP application with the West Virginia Commission requesting approval of a projected capital investment for 2017 of $27 million as part of a total five-year projected capital investment of $152 million. The new PREP customer rates would be effective November 1, 2016. This case is pending.

Dominion Carolina Gas

In June 2016, DCG received FERC authorization to construct and operate the approximately $45 million Columbia to Eastover Project facilities, which are expected to be placed into service in the fourth quarter of 2016.

Note 13. Variable Interest Entities

The primary beneficiary of a VIE is required to consolidate the VIE and to disclose certain information about its significant variable interests in the VIE. The primary beneficiary of a VIE is the entity that has both: 1) the power to direct the activities that most significantly impact the entity’s economic performance and 2) the obligation to absorb losses or receive benefits from the entity that could potentially be significant to the VIE.

Dominion

Dominion owns the general partner interest and 64.8% of the limited partnership interests in Dominion Midstream, which owns a preferred equity interest and the general partner interest in Cove Point. Additionally, Dominion owns the manager and 67% of the membership interest in certain merchant solar facilities, as discussed in Note 2. Dominion has concluded that these entities are VIEs due to the limited partners or members lacking the characteristics of a controlling financial interest. Dominion is the primary beneficiary of Dominion Midstream and the merchant solar facilities, and Dominion Midstream is the primary beneficiary of Cove Point, as they have the power to direct the activities that most significantly impact their economic performance as well as the obligation to absorb losses and benefits which could be significant to them.

Dominion has an initial 45% membership interest in Atlantic Coast Pipeline. See Note 9 to the Companies’ Annual Report on Form 10-K for the year ended December 31, 2015 for more details regarding the nature of this entity. Dominion concluded that Atlantic Coast Pipeline is a VIE because it has insufficient equity to finance its activities without additional subordinated financial support. Dominion has concluded that it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance, as the power to direct is shared among multiple unrelated parties. Dominion is obligated to provide capital contributions based on its ownership percentage. Dominion’s maximum exposure to loss is limited to its current and future investment.

Dominion and Virginia Power

Dominion and Virginia Power’s nuclear decommissioning trust funds and Dominion’s rabbi trusts hold investments in limited partnerships or similar type entities (see Note 10 for further details). Dominion and Virginia Power concluded that these partnership investments are VIEs due to the limited partners lacking the characteristics of a controlling financial interest. Dominion and Virginia Power have concluded neither is the primary beneficiary as they do not have the power to direct the activities that most significantly impact these VIEs’ economic performance. Dominion and Virginia Power are obligated to provide capital contributions to the partnerships as required by each partnership agreement based on their ownership percentages. Dominion and Virginia Power’s maximum exposure to loss is limited to their current and future investments.

Dominion and Dominion Gas

Dominion previously concluded that Iroquois was a VIE because a non-affiliated Iroquois equity holder had the ability during a limited period of time to transfer its ownership interests to another Iroquois equity holder or its affiliate. At the end of the first quarter of 2016, such right no longer existed and, as a result, Dominion concluded that Iroquois is no longer a VIE.

Virginia Power

Virginia Power had long-term power and capacity contracts with five non-utility generators; however, contracts with two of these generators expired in 2015, leaving three non-utility generators with an aggregate summer generation capacity of approximately 418 MW. These contracts contain certain variable pricing mechanisms in the form of partial fuel reimbursement that Virginia Power considers to be variable interests. After an evaluation of the information provided by these entities, Virginia Power was unable to determine whether they were VIEs. However, the information they provided, as well as Virginia Power’s knowledge of generation facilities in Virginia, enabled Virginia Power to conclude that, if they were VIEs, it would not be the primary beneficiary. This conclusion reflects Virginia Power’s determination that its variable interests do not convey the power to direct the most significant activities that impact the economic performance of the entities during the remaining terms of Virginia Power’s contracts and for the years the entities are expected to operate after its contractual relationships expire. The contracts expire at various dates ranging from 2017 to 2021. Virginia Power is not subject to any risk of loss from these potential VIEs other than its remaining purchase commitments which totaled $357 million as of June 30, 2016. Virginia Power paid $37 million and $55 million for electric capacity and $5 million and $23 million for electric energy to these entities in the

62

three months ended June 30, 2016 and 2015, respectively. Virginia Power paid $74 million and $108 million for electric capacity and $12 million and $60 million for electric energy to these entities in the six months ended June 30, 2016 and 2015, respectively.

Dominion Gas

DTI has been engaged to oversee the construction of, and to subsequently operate and maintain, the projects undertaken by Atlantic Coast Pipeline based on the overall direction and oversight of Atlantic Coast Pipeline’s members. An affiliate of DTI holds a membership interest in Atlantic Coast Pipeline, therefore DTI is considered to have a variable interest in Atlantic Coast Pipeline. The members of Atlantic Coast Pipeline hold the power to direct the construction, operations and maintenance activities of the entity. DTI has concluded it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance. DTI has no obligation to absorb any losses of the VIE. See Note 17 for information about associated related party receivable balances.

Virginia Power and Dominion Gas

Virginia Power and Dominion Gas purchased shared services from DRS, an affiliated VIE, of $74 million and $29 million for the three months ended June 30, 2016, $83 million and $30 million for the three months ended June 30, 2015, $188 million and $64 million for the six months ended June 30, 2016 and $166 million and $58 million for the six months ended June 30, 2015, respectively. Virginia Power and Dominion Gas determined that neither is the primary beneficiary of DRS as neither has both the power to direct the activities that most significantly impact its economic performance as well as the obligation to absorb losses and benefits which could be significant to it. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Virginia Power and Dominion Gas. Virginia Power and Dominion Gas have no obligation to absorb more than their allocated shares of DRS costs.

Note 14. 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 utilizes cash and letters of credit to fund collateral requirements. Collateral requirements are impacted by commodity prices, hedging levels, Dominion’s credit ratings and the credit quality of its counterparties.

Dominion

At June 30, 2016, Dominion’s commercial paper and letters of credit outstanding, as well as its capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	5,000	$	3,437	$	—	$	1,563
Joint revolving credit facility(1)		500		—		52		448
Total	$	5,500	$	3,437	$	52	$	2,011

(1) In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities can be used 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.

Virginia Power

Virginia Power’s short-term financing is supported through its access as co-borrower to the two joint revolving credit facilities. These credit facilities can be used for working capital, as support for the combined commercial paper programs of the Companies and for other general corporate purposes.

63

At June 30, 2016, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Dominion Gas, were as follows:

	Facility Limit(1)		Outstanding Commercial Paper		Outstanding Letters of Credit
(millions)
Joint revolving credit facility(1)	$	5,000	$	1,423	$	—
Joint revolving credit facility(1)		500		—		—
Total	$	5,500	$	1,423	$	—

(1) The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Virginia Power was $2.0 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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 has a $120 million credit facility. In May 2016, the maturity date for this facility was extended from April 2019 to April 2020. As of June 30, 2016, this facility supports $119 million of certain variable rate tax-exempt financings of Virginia Power.

Dominion Gas

Dominion Gas’ short-term financing is supported by its access as co-borrower to the two joint revolving credit facilities. These credit facilities 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, 2016, Dominion Gas’ share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Virginia Power were as follows:

	Facility Limit(1)		Outstanding Commercial Paper		Outstanding Letters of Credit
(millions)
Joint revolving credit facility(1)	$	1,000	$	238	$	—
Joint revolving credit facility(1)		500		—		—
Total	$	1,500	$	238	$	—

(1) A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Dominion Gas was $1.0 billion. If Dominion 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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.

Remarketable Subordinated Notes

In March 2016 and May 2016, Dominion successfully remarketed the $550 million 2013 Series A 1.07% RSNs due 2021 and the $550 million 2013 Series B 1.18% RSNs due 2019, respectively, pursuant to the terms of the related 2013 Equity Units. In connection with the remarketings, the interest rate on the Series A and Series B junior subordinated notes was reset to 4.104% and 2.962%, respectively, payable on a semi-annual basis and Dominion ceased to have the ability to redeem the notes at its option or defer interest payments. At June 30, 2016, the securities are included in junior subordinated notes in Dominion’s Consolidated Balance Sheets. Dominion did not receive any proceeds from the remarketings. Remarketing proceeds belonged to the investors holding the related 2013 Equity Units and were temporarily used to purchase a portfolio of treasury securities. Upon maturity of each portfolio, the proceeds were applied on behalf of investors on the related stock purchase contract settlement date to pay the purchase price to Dominion for issuance of 8.5 million shares of its common stock on both April 1, 2016 and July 1, 2016. See Issuance of Common Stock below for a description of common stock issued by Dominion in April 2016 and July 2016 under the stock purchase contracts.

Enhanced Junior Subordinated Notes

In the first quarter of 2016, Dominion purchased and cancelled $38 million and $4 million of the June 2006 hybrids and the September 2006 hybrids, respectively.

64

In July 2016, Dominion launched a tender offer to purchase up to $200 million in aggregate of additional June 2006 hybrids and September 2006 hybrids, which expired on August 1, 2016. In connection with the tender offer, Dominion purchased and cancelled $125 million and $74 million of the June 2006 hybrids and the September 2006 hybrids, respectively. All purchases were conducted in compliance with the applicable replacement capital covenants. Also in July 2016, Dominion issued $800 million of 5.25% July 2016 hybrids. The proceeds were used for general corporate purposes, including to finance the tender offer. The July 2016 hybrids are listed on the New York Stock Exchange under the symbol DRUA.

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

Long-term Debt

In May 2016, Dominion Gas issued $150 million of private placement 3.8% Senior Notes that mature in 2031. In June 2016, Dominion Gas issued $250 million of private placement 2.875% Senior Notes that mature in 2023. Also in June 2016, Dominion Gas issued €250 million of private placement 1.45% Senior Notes that mature in 2026. The notes were recorded at $280 million at issuance and included in long-term debt in the Consolidated Balance Sheets at $278 million at June 30, 2016.

Issuance of Common Stock

Dominion maintains Dominion Direct^® and a number of employee savings plans through which contributions may be invested in Dominion’s common stock. These shares may either be newly issued or purchased on the open market with proceeds contributed to these plans.

In December 2014, Dominion filed an SEC shelf registration for the sale of debt and equity securities including the ability to sell common stock through an at-the-market program. Also in December 2014, Dominion entered into four separate sales agency agreements to effect sales under the program and pursuant to which it may offer from time to time up to $500 million aggregate amount of its common stock. 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 and the sales agents and in conformance with applicable securities laws. Following issuances during the first and second quarters of 2015, Dominion has the ability to issue up to approximately $200 million of stock under the 2014 sales agency agreements; however, no additional issuances have occurred under these agreements in 2016.

In both April 2016 and July 2016, Dominion issued 8.5 million shares under the related stock purchase contract entered into as part of Dominion’s 2013 Equity Units. Additionally, Dominion completed a market issuance of equity in April 2016 of 10.2 million shares and receipt of proceeds of $756 million through a registered underwritten public offering. In connection with receipt of these proceeds, the acquisition financing commitments for the Questar Combination were reduced from $3.9 billion to $3.14 billion in April 2016.

Note 15. 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 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 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 financial position, liquidity or results of operations of the Companies.

65

Environmental Matters

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

Air

CAA

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

MATS

In December 2011, the EPA issued MATS for coal- and oil-fired electric utility steam generating units. The rule establishes strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. The rule includes a limited use provision for oil-fired units with annual capacity factors under 8% that provides an exemption from emission limits, and allows compliance with operational work practice standards. Compliance was required by April 16, 2015, with certain limited exceptions. However, in June 2014, the VDEQ granted a one-year MATS compliance extension for two coal-fired units at Yorktown power station to defer planned retirements and allow for continued operation of the units to address reliability concerns while necessary electric transmission upgrades are being completed. These coal units will need to continue operating until at least April 2017 due to delays in transmission upgrades needed to maintain electric reliability, which based on assumptions about the timing for required agency actions and construction schedules are expected to be completed by no earlier than the second quarter of 2017. Therefore, in October 2015, Virginia Power submitted a request to the EPA for an additional one year compliance extension under an EPA Administrative Order. The order was signed by the EPA in April 2016 allowing the Yorktown power station units to operate for up to one additional year, as required to maintain reliable power availability while transmission upgrades are being made.

In June 2015, the United States Supreme Court issued a decision holding that the EPA failed to take cost into account when the agency first decided to regulate the emissions from coal- and oil-fired plants, and remanded the MATS rule back to the United States Court of Appeals for the District of Columbia Circuit. However, the Supreme Court did not vacate or stay the effective date and implementation of the MATS rule. In November 2015, in response to the Supreme Court decision, the EPA proposed a supplemental finding that consideration of cost does not alter the agency’s previous conclusion that it is appropriate and necessary to regulate coal- and oil-fired electric utility steam generating units under Section 112 of the CAA. In December 2015, the District of Columbia Court of Appeals issued an order remanding the MATS rulemaking proceeding back to the EPA without setting aside judgment, noting that EPA had represented it was on track to issue a final finding regarding its consideration of cost. In April 2016, the EPA issued a final supplemental finding that consideration of costs does not alter its conclusion regarding appropriateness and necessity for the regulation. These actions do not change Virginia Power’s plans to close coal units at Yorktown power station or the need to complete necessary electricity transmission upgrades by 2017. Since the MATS rule remains in effect and Dominion is complying with the requirements of the rule, Dominion does not expect any adverse impacts to its operations at this time.

CAIR

The EPA established CAIR with the intent to require significant reductions in SO₂ and NO_X emissions from electric generating facilities. In July 2008, the United States Court of Appeals for the District of Columbia Circuit issued a ruling vacating CAIR. In December 2008, the Court denied rehearing, but also issued a decision to remand CAIR to the EPA. In July 2011, the EPA issued a replacement rule for CAIR, called CSAPR, that required 28 states to reduce power plant emissions that cross state lines. CSAPR established new SO₂ and NO_X emissions cap and trade programs that were completely independent of the current ARP. Specifically, CSAPR required reductions in SO₂ and NO_X emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NO_X emissions caps, NO_X emissions caps during the ozone season (May 1 through September 30) and annual SO₂ emission caps with differing requirements for two groups of affected states.

CSAPR

Following numerous petitions by industry participants for review and a successful motion for stay, in October 2014, the United States Court of Appeals for the District of Columbia Circuit ordered that the EPA’s motion to lift the stay of CSAPR be granted. Further, the Court granted the EPA’s request to shift the CSAPR compliance deadlines by three years, so that Phase 1 emissions budgets (which would have gone into effect in 2012 and 2013) will apply in 2015 and 2016, and Phase 2 emissions budgets will apply in 2017 and beyond. CSAPR replaced CAIR beginning in January 2015. The cost to comply is not expected to be material to Dominion’s or Virginia Power’s Consolidated Financial Statements. Future outcomes of any additional litigation and/or any action to issue a revised rule, including the EPA’s recent proposal to reduce the ozone season NO_X emission budgets beginning in 2017, could affect the assessment regarding cost of compliance.

66

Ozone Standards

In October 2015, the EPA issued a final rule tightening the ozone standard, set in 2008, from 75-ppb to 70-ppb. The EPA is expected to complete attainment designations for a new standard by December 2017 and states will have until 2020 or 2021 to develop plans to address the new standard. To comply with the 2008 standard, in April 2016 Dominion submitted the NO_X Reasonable Available Control Technology analysis for Unit 5 at Possum Point power station. Until the states have developed implementation plans, the Companies are unable to predict whether or to what extent the new rules will ultimately require additional controls. However, if significant expenditures are required to implement additional controls, it could adversely affect the Companies’ results of operations and cash flows.

NO_x and VOC Emissions

In April 2014, the Pennsylvania Department of Environmental Protection issued proposed regulations to reduce NO_X and VOC emissions from combustion sources. The regulations were finalized in April 2016. To comply with the regulations, Dominion Gas anticipates 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 $25 million.

NSPS

In August 2012, the EPA issued the first 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 September 2015, the EPA issued a proposed NSPS (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. The proposed regulation was finalized in June 2016. All projects which commenced construction after September 2015 will be required to comply with this regulation. Dominion and Dominion Gas are implementing the final regulation. Dominion currently estimates the potential impacts on results of operations, financial condition and/or cash flows related to this matter to be immaterial. Dominion Gas is still evaluating whether potential impacts on results of operations, financial condition and/or cash flows related to this matter will be material.

Methane Emissions

In January 2015, as part of its Climate Action Plan, the EPA announced plans to reduce methane emissions from the oil and gas sector including natural gas processing and transmission sources. In July 2015, the EPA announced the next generation of its voluntary Natural Gas STAR program, the Natural Gas STAR Methane Challenge Program. The proposed 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, Dominion joined the EPA as a founding partner in this program for its distribution companies, East Ohio and Hope, and DTI.

In March 2016, as part of President Obama’s Climate Action Plan, the EPA began development of regulations for reducing methane emissions from existing sources in the oil and natural gas sectors. In June 2016, the EPA issued a draft Information Collection Request to collect information on existing sources upstream of distribution in this sector. The final Information Collection Request is expected in the fourth quarter of 2016. Depending on the results of this Information Collection Request effort, the EPA may propose new regulations on existing sources. Dominion and Dominion Gas cannot currently estimate the potential impacts on results of operations, financial condition and/or cash flows related to this matter.

Climate Change Legislation and Regulation

In October 2013, the United States Supreme Court granted petitions filed by several industry groups, states, and the United States Chamber of Commerce seeking review of the United States Court of Appeals for the District of Columbia Circuit’s June 2012 decision upholding the EPA’s regulation of GHG emissions from stationary sources under the CAA’s permitting programs. In June 2014, the United States Supreme Court ruled that the EPA lacked the authority under the CAA to require PSD or Title V permits for stationary sources based solely on GHG emissions. However, the Court upheld the EPA’s ability to require BACT for GHG for sources that are otherwise subject to PSD or Title V permitting for conventional pollutants. In July 2014, the EPA issued a memorandum specifying that it will no longer apply or enforce federal regulations or EPA-approved PSD state implementation plan provisions that require new and modified stationary sources to obtain a PSD permit when GHGs are the only pollutant that would be emitted at levels that exceed the permitting thresholds. In August 2015, the EPA published a final rule rescinding the requirement for all new and modified major sources to obtain permits based solely on their GHG emissions. In addition, the EPA stated that it will continue to use the existing thresholds to apply to sources that are otherwise subject to PSD for conventional pollutants until it completes a new rulemaking either justifying and upholding those thresholds or setting new ones. Some states have issued interim guidance that follows the EPA guidance. Due to uncertainty regarding what additional actions states may take to amend their existing regulations and what action the EPA ultimately takes to address the Court ruling under a new rulemaking, the Companies cannot predict the impact to their financial statements at this time.

67

In July 2011, the EPA signed a final rule deferring the need for PSD and Title V permitting for CO₂ emissions for biomass projects. This rule temporarily deferred for a period of up to three years 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. The deferral policy expired in July 2014. In July 2013, the United States Court of Appeals for the District of Columbia Circuit vacated this rule; however, a mandate making this decision effective has not been issued. Virginia Power converted three coal-fired generating stations, Altavista, Hopewell and Southampton, to biomass during the CO₂ deferral period. It is unclear how the court’s decision or the EPA’s final policy regarding the treatment of specific feedstock will affect biomass sources that were permitted during the deferral period; however, the expenditures to comply with any new requirements could be material to Dominion’s and Virginia Power’s financial statements.

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 and Virginia Power have 14 and 11 facilities, respectively, that may be subject to the final regulations. Dominion anticipates that it will have to install impingement control technologies at many of these stations that have once-through cooling systems. Dominion 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’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 that may be subject to additional wastewater treatment requirements associated with the final rule. The expenditures to comply with these new requirements are expected to be material.

Solid and Hazardous Waste

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 United States 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 United States government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.

From time to time, Dominion, Virginia Power, or Dominion 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. Each party can be held jointly, severally and strictly liable for the cleanup costs. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion, Virginia Power, or Dominion 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. Except as noted below, the Companies do not believe this will have a material effect on results of operations, financial condition and/or cash flows.

68

In September 2011, the EPA issued a UAO to Virginia Power and 22 other parties, ordering specific remedial action of certain areas at the Ward Transformer Superfund site located in Raleigh, North Carolina. Virginia Power does not believe it is a liable party under CERCLA based on its alleged connection to the site. In November 2011, Virginia Power and a number of other parties notified the EPA that they are declining to undertake the work set forth in the UAO.

The EPA may seek to enforce a UAO in court pursuant to its enforcement authority under CERCLA, and may seek recovery of its costs in undertaking removal or remedial action. If the court determines that a respondent failed to comply with the UAO without sufficient cause, the EPA may also seek civil penalties of up to $37,500 per day for the violation and punitive damages of up to three times the costs incurred by the EPA as a result of the party’s failure to comply with the UAO. Virginia Power is currently unable to make an estimate of the potential financial statement impacts related to the Ward Transformer matter.

Dominion has determined that it is associated with 17 former manufactured gas plant sites, three of which pertain to Virginia Power and 12 of which pertain to Dominion 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 one of the former sites, Dominion is conducting a state-approved post closure groundwater monitoring program and an environmental land use restriction has been recorded. Another site has been accepted into a state-based voluntary remediation program. Virginia Power is currently evaluating the nature and extent of the contamination from this site as well as potential remedial options. Preliminary costs for options under evaluation for the site range from $1 million to $22 million. 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

Following the completion of the Appalachian Gateway project in 2012, DTI received multiple change order requests and other claims for additional payments from a pipeline contractor for the project. In July 2013, DTI filed a complaint in United States District Court for the Eastern District of Virginia for breach of contract as well as accounting and declaratory relief. The contractor filed a motion to dismiss, or in the alternative, a motion to transfer venue to Pennsylvania and/or West Virginia, where the pipelines were constructed. DTI filed an opposition to the contractor’s motion in August 2013. In November 2013, the court granted the contractor’s motion on the basis that DTI must first comply with the dispute resolution process. In July 2015, the contractor filed a complaint against DTI in United States District Court for the Western District of Pennsylvania. In August 2015, DTI filed a motion to dismiss, or in the alternative, a motion to transfer venue to Virginia. In March 2016, the Pennsylvania court granted the motion to dismiss and transferred the case to the United States District Court for the Eastern District of Virginia. In April 2016, the Virginia court issued an order staying the proceedings and ordering mediation. A mediation occurred in May 2016 but was unsuccessful. In July 2016, DTI filed a motion to dismiss. This case is pending. DTI has accrued a liability of $6 million for this matter. Dominion Gas cannot currently estimate additional financial statement impacts, but there could be a material impact to its financial condition and/or cash flows.

Ash Pond and Landfill Closure Costs

In September 2014, Virginia Power received a notice from the Southern Environmental Law Center on behalf of the Potomac Riverkeeper and Sierra Club alleging CWA violations at Possum Point power station. The notice alleges unpermitted discharges to surface water and groundwater from Possum Point power station’s historical and active ash storage facilities. A similar notice from the Southern Environmental Law Center on behalf of the Sierra Club was subsequently received related to Chesapeake power station. In December 2014, Virginia Power offered to close all of its coal ash ponds and landfills at Possum Point power station, Chesapeake and Bremo power stations as settlement of the potential litigation. While the issue is open to potential further negotiations, the Southern Environmental Law Center declined the offer as presented in January 2015 and, in March 2015, filed a lawsuit related to its claims of the alleged CWA violations at Chesapeake power station. Virginia Power filed a motion to dismiss in April 2015, which was denied in November 2015. A trial was held in June 2016. This case is pending. As a result of the December 2014 settlement offer, Virginia Power recognized a charge of $121 million in other operations and maintenance expense in its Consolidated Statements of Income in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2014.

69

In April 2015, the EPA’s final rule regulating the management of CCRs stored in impoundments (ash ponds) and landfills was published in the Federal Register. The final rule regulates 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. The enactment of the final rule in April 2015 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 April 2016, the EPA announced a partial settlement with certain environmental and industry organizations that had challenged the final CCR rule in the United States Court of Appeals for the District of Columbia Circuit. As part of the settlement, certain exemptions included in the final rule for inactive ponds that closed by April 2018 will be removed, resulting in inactive ponds ultimately being subject to the same requirements as existing ponds. In June 2016, the court issued an order approving the settlement, which requires the EPA to modify provisions in the final CCR rule concerning inactive ponds. Virginia Power does not believe this change will substantially impact its closure plans for inactive ponds.

In 2015, Virginia Power recorded a $386 million ARO related to future ash pond and landfill closure costs. Recognition of the ARO also resulted in a $99 million incremental charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $166 million increase in property, plant, and equipment associated with asset retirement costs, and a $121 million reduction in other noncurrent liabilities related to reversal of the contingent liability described above since the ARO obligation created by the final CCR rule represents similar activities. Virginia Power is in the process of obtaining the necessary permits to complete the work. In February and March 2016, respectively, two parties filed administrative appeals in the Circuit Court for the City of Richmond challenging certain provisions, relating to ash pond dewatering activities, of Possum Point power station’s wastewater discharge permit issued by the VDEQ in January 2016. One of those parties withdrew its appeal in June 2016. Virginia Power cannot predict the financial impact associated with the remaining appeal, but believes that it will not be material. The actual AROs related to the CCR rule may vary substantially from the estimates used to record the increased obligation in 2015.

Cove Point

Dominion is constructing the Liquefaction Project at the Cove Point facility, which would enable the facility to liquefy domestically-produced natural gas and export it as LNG. In September 2014, FERC issued an order granting authorization for Cove Point to construct, modify and operate the Liquefaction Project. In October 2014, several parties filed a motion with FERC to stay the order and requested rehearing. In May 2015, FERC denied the requests for stay and rehearing.

Two parties have separately filed petitions for review of the FERC order in the United States Court of Appeals for the District of Columbia Circuit, which petitions have been 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. Cove Point believes that on remand FERC will be able to justify its decision.

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 United States nuclear operators, Dominion 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 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

70

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 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 and Virginia Power do not expect material financial impacts related to compliance with Tier 2 and Tier 3 recommendations.

Guarantees, Surety Bonds and Letters of Credit

Dominion

At June 30, 2016, Dominion had issued $73 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of June 30, 2016, Dominion’s exposure under these guarantees was $43 million, primarily related to certain reserve requirements associated with non-recourse financing.

Dominion also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. To the extent that a liability subject to a guarantee has been incurred by one of Dominion’s consolidated subsidiaries, that liability is included in the Consolidated Financial Statements. Dominion 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 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, 2016, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	27	$	27
Commodity transactions(3)		2,074		864
Nuclear obligations(4)		189		81
Cove Point(5)		1,900		—
Solar(6)		1,514		244
Other(7)		420		28
Total	$	6,124	$	1,244

(1) Represents the estimated portion of the guarantee’s stated limit that is utilized as of June 30, 2016 based upon prevailing economic conditions and fact patterns specific to each guarantee arrangement. For those guarantees related to obligations that are recorded as liabilities by Dominion’s subsidiaries, the value includes the recorded amount.

(2) Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, Dominion would be obligated to repay such amounts.

(3) Guarantees related to commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and related commodities and services. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion would be obligated to satisfy such obligation. Dominion and its subsidiaries receive similar guarantees as collateral for credit extended to others. The value provided includes certain guarantees that do not have stated limits.

(4) Guarantees related to certain DEI subsidiaries’ potential retrospective premiums that could be assessed if there is a nuclear incident under Dominion’s nuclear insurance programs and guarantees for a DEI subsidiary’s and Virginia Power’s commitment to buy nuclear fuel. Excludes Dominion’s agreement to provide up to $150 million and $60 million to two DEI subsidiaries to pay the operating expenses of Millstone nuclear power station (in the event of a prolonged outage) and Kewaunee nuclear power station, respectively, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee nuclear power station also provides for funds through the completion of decommissioning.

(5) Guarantees related to Cove Point, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.

(6) Includes guarantees to facilitate the development of solar projects including guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.

(7) Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries’ obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of June 30, 2016, Dominion’s maximum remaining cumulative exposure under these equity funding agreements is $45 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.

71

Additionally, at June 30, 2016, Dominion had purchased $120 million of surety bonds, including $69 million at Virginia Power and $21 million at Dominion Gas, and authorized the issuance of letters of credit by financial institutions of $52 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 16. 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, 2015.

At June 30, 2016, Dominion’s credit exposure related to energy marketing and price risk management activities totaled $111 million. Of this amount, investment grade counterparties, including those internally rated, represented 88%. No single counterparty, whether investment grade or non-investment grade, exceeded $31 million of exposure.

Credit-Related Contingent Provisions

The majority of Dominion’s derivative instruments contain credit-related contingent provisions. These provisions require Dominion 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, 2016 and December 31, 2015, Dominion would have been required to post an additional $4 million and $12 million, respectively, of 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 had not posted any collateral at June 30, 2016 or December 31, 2015 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The collateral posted includes any amounts paid related to non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. 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 as of June 30, 2016 and December 31, 2015 was $13 million and $49 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power and Dominion Gas were not material as of June 30, 2016 and December 31, 2015. See Note 9 for further information about derivative instruments.

Note 17. Related-Party Transactions

Virginia Power and Dominion Gas engage in related-party transactions primarily with other Dominion subsidiaries (affiliates). Virginia Power’s and Dominion 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 Gas are included in Dominion’s consolidated federal income tax return. Dominion’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 physical forwards and options, to manage commodity price risks associated with purchases of natural gas. As of June 30, 2016, Virginia Power’s derivative assets and liabilities with affiliates were each $36 million and $3 million, respectively. As of December 31, 2015, Virginia Power’s derivative assets and liabilities with affiliates were $13 million and $22 million, respectively. See Note 9 for more information.

Virginia Power participates in certain Dominion benefit plans described in Note 18. In Virginia Power’s Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, amounts due to Dominion associated with these benefit plans included in other deferred credits and other liabilities were $356 million and $316 million, respectively, and amounts due from Dominion at June 30, 2016 and December 31, 2015 included in other deferred charges and other assets were $98 million and $77 million, respectively.

DRS 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.

72

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Commodity purchases from affiliates	$	99	$	94	$	244	$	346
Services provided by affiliates(1)		102		107		242		217
Services provided to affiliates		7		5		12		10

(1) Includes capitalized expenditures of $38 million for both the three months ended June 30, 2016 and 2015, respectively, and $77 million and $73 million for the six months ended June 30, 2016 and 2015, respectively.

Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. Virginia Power had no short-term demand note borrowings from Dominion as of June 30, 2016. There were $376 million in short-term demand note borrowings from Dominion as of December 31, 2015. Virginia Power had no outstanding borrowings under the Dominion money pool for its nonregulated subsidiaries as of June 30, 2016 and December 31, 2015. Interest charges related to Virginia Power’s borrowings from Dominion were immaterial for the three and six months ended June 30, 2016 and 2015.

There were no issuances of Virginia Power’s common stock to Dominion for the three and six months ended June 30, 2016 and 2015.

Dominion Gas

Transactions with Related Parties

Dominion Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Gas provides transportation and storage services to affiliates. Dominion Gas also enters into certain other contracts with affiliates, which are presented separately from contracts involving commodities or services. As of June 30, 2016 and December 31, 2015, all of Dominion Gas’ commodity derivatives were with affiliates. See Notes 7 and 9 for more information.

Dominion Gas participates in certain Dominion benefit plans as described in Note 18. In Dominion Gas’ Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, amounts due from Dominion associated with these benefit plans included in noncurrent pension and other postretirement benefit assets were $674 million and $652 million, respectively, and amounts due to Dominion at June 30, 2016 and December 31, 2015 included in other deferred credits and other liabilities were immaterial.

DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to related parties, including technical services. The amounts recognized for these services were as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Purchases of natural gas and transportation and storage services from affiliates	$	2	$	2	$	5	$	4
Sales of natural gas and transportation and storage services to affiliates		18		17		35		35
Services provided by related parties(1)		33		34		72		68
Services provided to related parties (2)		33		25		60		45

(1) Includes capitalized expenditures of $14 million and $15 million for the three months ended June 30, 2016 and 2015, respectively, and $24 million for both the six months ended June 30, 2016 and 2015.

(2) Amounts primarily attributable to Atlantic Coast Pipeline.

The following table presents affiliated and related-party activity reflected in Dominion Gas’ Consolidated Balance Sheets:

	June 30, 2016		December 31, 2015
(millions)
Other receivables(1)	$	8	$	7
Customer receivables from related parties		10		4
Imbalances receivable from affiliates(2)		3		1
Affiliated notes receivable(3)		16		14

73

(1) Represents amounts due from Atlantic Coast Pipeline, a related-party VIE.

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

(3) Amounts are presented in other deferred charges and other assets in Dominion Gas’ Consolidated Balance Sheets.

Dominion Gas’ borrowings under the intercompany revolving credit agreement with Dominion were immaterial and $95 million as of June 30, 2016 and December 31, 2015, respectively. Interest charges related to Dominion Gas’ total borrowings from Dominion were immaterial for the three and six months ended June 30, 2016 and 2015.

Note 18. Employee Benefit Plans

In the first quarter of 2016, the Companies announced an organizational design initiative that will reduce their total workforces during 2016. The goal of the organizational design initiative was to streamline leadership structure and push decision making lower while also improving efficiency. During the six months ended June 30, 2016, Dominion recorded a $65 million ($40 million after-tax) charge, including $33 million ($20 million after-tax) at Virginia Power and $8 million ($5 million after-tax) at Dominion Gas, primarily reflected in other operations and maintenance expense in their Consolidated Statements of Income due to severance pay and other costs related to the organizational design initiative. The terms of the severance under the organizational design initiative were consistent with the Companies’ existing severance plans.

Dominion

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

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
(millions)
Three Months Ended June 30,
Service cost	$	28		$	31		$	8		$	10
Interest cost		78			72			17			16
Expected return on plan assets		(139	)		(133	)		(30	)		(30	)
Amortization of prior service cost (credit)		1			1			(7	)		(6	)
Amortization of net actuarial loss		27			40			2			2
Net periodic benefit cost (credit)	$	(5	)	$	11		$	(10	)	$	(8	)
Six Months Ended June 30,
Service cost	$	57		$	63		$	16		$	20
Interest cost		155			144			34			33
Expected return on plan assets		(278	)		(266	)		(59	)		(59	)
Amortization of prior service cost (credit)		1			1			(14	)		(13	)
Amortization of net actuarial loss		55			80			3			3
Net periodic benefit cost (credit)	$	(10	)	$	22		$	(20	)	$	(16	)

Employer Contributions

During the six months ended June 30, 2016, Dominion made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs during the remainder of 2016.

Dominion Gas

Dominion Gas participates in certain Dominion 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, 2015. See Note 17 for more information.

74

The components of Dominion Gas’ provision for net periodic benefit credit for employees represented by collective bargaining units were as follows:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
(millions)
Three Months Ended June 30,
Service cost	$	4		$	4		$	2		$	1
Interest cost		7			7			4			4
Expected return on plan assets		(34	)		(32	)		(7	)		(6	)
Amortization of net actuarial loss		4			5			1			—
Net periodic benefit credit	$	(19	)	$	(16	)	$	—		$	(1	)
Six Months Ended June 30,
Service cost	$	7		$	7		$	3		$	3
Interest cost		15			14			7			7
Expected return on plan assets		(67	)		(63	)		(12	)		(12	)
Amortization of net actuarial loss		7			10			1			1
Net periodic benefit credit	$	(38	)	$	(32	)	$	(1	)	$	(1	)

Employer Contributions

During the six months ended June 30, 2016, Dominion Gas made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion 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 2016.

Note 19. Operating Segments

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

Primary Operating Segment	Description of Operations	Dominion	Virginia Power	Dominion Gas
DVP	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
Dominion Generation	Regulated electric fleet	X	X
	Merchant electric fleet	X
Dominion Energy	Gas transmission and storage(1)	X		X
	Gas distribution and storage	X		X
	Gas gathering and processing	X		X
	LNG import and storage	X
	Nonregulated retail energy marketing(2)	X

(1) Includes remaining producer services activities for Dominion.

(2) As a result of Dominion’s decision to realign its business units effective for 2015 year-end reporting, nonregulated retail energy marketing operations were moved from the Dominion Generation segment to the Dominion Energy segment.

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

Dominion

The Corporate and Other Segment of Dominion includes its corporate, service company and other functions (including unallocated debt) and the net impact of operations that are discontinued or sold. In addition, Corporate and Other includes specific items attributable to Dominion’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, 2016, Dominion reported an after-tax net expense of $37 million for specific items in the Corporate and Other segment, with $26 million of these net expenses attributable to its operating segments. In the six months ended June 30, 2015, Dominion reported an after-tax net expense of $64 million for specific items in the Corporate and Other segment, with $62 million of these net expenses attributable to its operating segments.

75

The net expense for specific items attributable to Dominion’s operating segments in 2016 primarily related to the impact of the following item:

• A $59 million ($36 million after-tax) charge related to an organizational design initiative, attributable to:

• DVP ($5 million after-tax);

• Dominion Energy ($12 million after-tax); and

• Dominion Generation ($19 million after-tax).

The net expense for specific items in 2015 primarily related to the impact of the following items, all of which were attributable to Dominion Generation:

• An $85 million ($52 million after-tax) write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015;

• A $45 million ($28 million after-tax) charge related to incremental future ash pond and landfill closure costs at certain utility generation facilities due to the enactment of the final CCR rule in April 2015; and

• A $17 million ($10 million after-tax) billing adjustment related to PJM; partially offset by

• A $45 million ($28 million after-tax) net gain on investments held in nuclear decommissioning trust funds.

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

	DVP		Dominion Generation(1)		Dominion Energy(1)		Corporate and Other			Adjustments/ Eliminations(1)			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Total revenue from external customers	$	512	$	1,564	$	391	$	3		$	128		$	2,598
Intersegment revenue		6		2		124		133			(265	)		—
Total operating revenue		518		1,566		515		136			(137	)		2,598
Net income attributable to Dominion		104		171		162		15			—			452
Three Months Ended June 30, 2015
Total revenue from external customers	$	500	$	1,652	$	463	$	4		$	128		$	2,747
Intersegment revenue		5		6		115		144			(270	)		—
Total operating revenue		505		1,658		578		148			(142	)		2,747
Net income (loss) attributable to Dominion		117		250		129		(83	)		—			413
Six Months Ended June 30, 2016
Total revenue from external customers	$	1,068	$	3,257	$	876	$	6		$	312		$	5,519
Intersegment revenue		11		5		302		325			(643	)		—
Total operating revenue		1,079		3,262		1,178		331			(331	)		5,519
Net income (loss) attributable to Dominion		224		416		348		(12	)		—			976
Six Months Ended June 30, 2015
Total revenue from external customers	$	1,064	$	3,641	$	999	$	(9	)	$	461		$	6,156
Intersegment revenue		10		9		425		286			(730	)		—
Total operating revenue		1,074		3,650		1,424		277			(269	)		6,156
Net income (loss) attributable to Dominion		257		512		356		(176	)		—			949

(1) 2015 amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.

Intersegment sales and transfers for Dominion 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, 2016, Virginia Power reported an after-tax net expense of $19 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments. In the six months ended June 30, 2015, Virginia Power reported an after-tax net expense of $87 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments.

76

The net expense for specific items attributable to Virginia Power’s operating segments in 2016 primarily related to the impact of the following item:

• A $33 million ($20 million after-tax) charge related to an organizational design initiative, attributable to:

• DVP ($5 million after-tax); and

• Dominion Generation ($15 million after-tax).

The net expense for specific items in 2015 primarily related to the impact of the following items, all of which were attributable to Dominion Generation:

• An $85 million ($52 million after-tax) write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015;

• A $45 million ($28 million after-tax) charge related to incremental future ash pond and landfill closure costs at certain utility generation facilities due to the enactment of the final CCR rule in April 2015; and

• A $15 million ($9 million after-tax) billing adjustment related to PJM.

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

	DVP		Dominion Generation		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Operating revenue	$	512	$	1,264	$	—		$	1,776
Net income		104		174		2			280
Three Months Ended June 30, 2015
Operating revenue	$	502	$	1,311	$	—		$	1,813
Net income (loss)		117		155		(26	)		246
Six Months Ended June 30, 2016
Operating revenue	$	1,069	$	2,597	$	—		$	3,666
Net income (loss)		222		340		(19	)		543
Six Months Ended June 30, 2015
Operating revenue	$	1,069	$	2,896	$	(15	)	$	3,950
Net income (loss)		257		345		(87	)		515

Dominion Gas

The Corporate and Other Segment of Dominion Gas primarily includes specific items attributable to Dominion 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 Gas as a result of Dominion’s basis in the net assets contributed.

In the six months ended June 30, 2016, Dominion Gas reported an after-tax net expense of $2 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segment. In the six months ended June 30, 2015, Dominion Gas reported no amounts for specific items in the Corporate and Other segment.

The net expense for specific items in 2016 primarily related to an $8 million ($5 million after-tax) charge related to an organizational design initiative.

77

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

	Dominion     Energy		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Operating revenue	$	368	$	—		$	368
Net income (loss)		108		(3	)		105
Three Months Ended June 30, 2015
Operating revenue	$	395	$	—		$	395
Net income (loss)		87		(2	)		85
Six Months Ended June 30, 2016
Operating revenue	$	799	$	—		$	799
Net income (loss)		211		(8	)		203
Six Months Ended June 30, 2015
Operating revenue	$	926	$	—		$	926
Net income (loss)		251		(5	)		246

78

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS

OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

MD&A discusses Dominion’s results of operations and general financial condition and Virginia Power’s and Dominion Gas’ results of operations. MD&A should be read in conjunction with the Companies’ Consolidated Financial Statements. Virginia Power and Dominion 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

• Dominion

• Results of Operations

• Segment Results of Operations

• Virginia Power

• Results of Operations

• Dominion Gas

• Results of Operations

• Liquidity and Capital Resources - Dominion

• Future Issues and Other Matters - Dominion

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 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;

• 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 emissions, 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;

• 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’s and Dominion 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 and Virginia Power and in benefit plan trusts by Dominion and Dominion Gas;

79

• 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 Midstream, and retirements of assets based on asset portfolio reviews;

• The expected timing and likelihood of completion of the Questar Combination, including the terms and conditions of any required regulatory approvals;

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

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

• Changes in rules for regional transmission organizations and independent system operators in which Dominion 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 and Dominion 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’s merchant generation facilities operate, and competition in the development, construction and ownership of certain electric transmission facilities in Virginia Power’s service territory in connection with FERC 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 and Dominion Gas;

• Changes in operating, maintenance and construction costs;

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

• The inability to complete planned construction, conversion or expansion projects at all, or with the outcomes or within the terms and time frames initially anticipated;

• 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, 2015.

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, 2016, 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, 2015. The policies disclosed included the accounting for regulated operations, AROs, income taxes, derivative contracts and other instruments at fair value, goodwill and long-lived asset impairment testing and employee benefit plans.

80

Dominion

Results of Operations

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

	2016		2015		$ Change
(millions, except EPS)
Second Quarter
Net income attributable to Dominion	$	452	$	413	$	39
Diluted EPS		0.73		0.70		0.03
Year-To-Date
Net income attributable to Dominion	$	976	$	949	$	27
Diluted EPS		1.61		1.60		0.01

Overview

Second Quarter 2016 vs. 2015

Net income attributable to Dominion increased 9%, primarily due to the absence of charges related to ash pond and landfill closure costs at certain utility generation facilities, a decrease in electric utility capacity related expenses and an increase in gains from agreements to convey shale development rights underneath several natural gas storage fields. These increases were partially offset by a decrease in electric utility sales to retail customers from a reduction in cooling degree days.

Year-To-Date 2016 vs. 2015

Net income attributable to Dominion increased 3%, primarily due to the absence of the write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015 and higher anticipated renewable energy investment tax credits. These increases were partially offset by a decrease in electric utility sales to retail customers from reductions in cooling and heating degree days and organizational design initiative costs.

Analysis of Consolidated Operations

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

	Second Quarter							Year-To-Date
	2016		2015		$ Change			2016		2015		$ Change
(millions)
Operating revenue	$	2,598	$	2,747	$	(149	)	$	5,519	$	6,156	$	(637	)
Electric fuel and other energy-related purchases		551		591		(40	)		1,185		1,544		(359	)
Purchased electric capacity		45		90		(45	)		113		184		(71	)
Purchased gas		56		111		(55	)		175		361		(186	)
Net revenue		1,946		1,955		(9	)		4,046		4,067		(21	)
Other operations and maintenance		665		709		(44	)		1,368		1,311		57
Depreciation, depletion and amortization		361		339		22			712		682		30
Other taxes		139		134		5			303		299		4
Other income		72		56		16			126		116		10
Interest and related charges		239		221		18			465		444		21
Income tax expense		152		190		(38	)		331		489		(158	)

An analysis of Dominion’s results of operations follows:

Second Quarter 2016 vs. 2015

Net revenue decreased 1%, primarily reflecting:

• A $25 million decrease from merchant generation operations, primarily due to lower volumes mainly from increased planned and unplanned outage days in the second quarter of 2016 ($59 million), partially offset by higher realized prices ($14 million) and an increase due to additional solar generating facilities ($9 million); and

• An $8 million decrease from regulated natural gas transmission operations, primarily due to decreased demand charges.

These decreases were partially offset by a $30 million increase from electric utility operations, primarily reflecting:

• A net decrease in capacity related expenses ($43 million);

81

• An increase from rate adjustment clauses ($33 million); and

• An increase in sales to customers due to the effect of changes in customer usage and other factors ($7 million); partially offset by

• A decrease in sales to retail customers from a reduction in cooling degree days ($58 million).

Other operations and maintenance decreased 6%, primarily reflecting:

• The absence of a $45 million charge related to ash pond and landfill closure costs at certain utility generation facilities; and

• An increase in gains from agreements to convey shale development rights underneath several natural gas storage fields ($34 million).

These decreases were partially offset by:

• A $40 million increase in planned outage costs primarily due to an increase in scheduled outage days at certain merchant generation facilities; and

• A $16 million increase in storm damage and service restoration costs.

Income tax expense decreased 20%, primarily due to higher anticipated renewable energy investment tax credits ($21 million) and the impact of a state legislative change ($17 million).

Year-To-Date 2016 vs. 2015

Net revenue decreased 1%, primarily reflecting:

• A $42 million decrease from regulated natural gas distribution operations, primarily due to a decrease in rate adjustment clause revenue related to low income assistance programs ($34 million) and a decrease in sales to customers due to a reduction in heating degree days ($11 million);

• A $39 million decrease from merchant generation operations, primarily due to lower volumes mainly from increased planned and unplanned outage days ($63 million), partially offset by an increase due to additional solar generating facilities ($16 million); and

• A $27 million decrease from regulated natural gas transmission operations, primarily due to:

• A $31 million decrease in gas transportation and storage activities, primarily due to decreased demand charges ($19 million), decreased fuel retained ($11 million) and decreased regulated gas sales ($13 million), partially offset by DCG activities ($10 million); and

• A $9 million decrease in NGL activities, due to decreased volumes ($7 million) and prices ($2 million); partially offset by

• A $15 million increase due to services performed for Atlantic Coast Pipeline.

These decreases were partially offset by an $83 million increase from electric utility operations, primarily reflecting:

• The absence of an $85 million write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015;

• A net decrease in capacity related expenses ($66 million); and

• An increase from rate adjustment clauses ($51 million); partially offset by

• A decrease in sales to retail customers from reductions in cooling and heating degree days ($132 million).

Other operations and maintenance increased 4%, primarily reflecting:

• Organizational design initiative costs ($64 million);

• A decrease in gains from agreements to convey shale development rights underneath several natural gas storage fields ($31 million);

• A $39 million increase in planned outage costs primarily due to an increase in scheduled outage days at certain merchant generation facilities;

• A $19 million increase in storm damage and service restoration costs; and

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

These increases were partially offset by:

• The absence of a $45 million charge related to ash pond and landfill closure costs at certain utility generation facilities; and

• A decrease in bad debt expense at regulated natural gas distribution operations primarily related to low income assistance programs ($34 million). These bad debt expenses are recovered through rates and do not impact net income.

82

Income tax expense decreased 32%, primarily due to higher anticipated renewable energy investment tax credits ($90 million), lower pretax income ($48 million) and the impact of a state legislative change ($17 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’s operating segments to net income attributable to Dominion:

	Net Income attributable to Dominion									Diluted EPS
	2016			2015			$ Change			2016			2015			$ Change
(millions, except EPS)
Second Quarter
DVP	$	104		$	117		$	(13	)	$	0.17		$	0.20		$	(0.03	)
Dominion Generation(1)		171			250			(79	)		0.28			0.42			(0.14	)
Dominion Energy(1)		162			129			33			0.26			0.22			0.04
Primary operating segments		437			496			(59	)		0.71			0.84			(0.13	)
Corporate and Other		15			(83	)		98			0.02			(0.14	)		0.16
Consolidated	$	452		$	413		$	39		$	0.73		$	0.70		$	0.03
Year-To-Date
DVP	$	224		$	257		$	(33	)	$	0.37		$	0.43		$	(0.06	)
Dominion Generation(1)		416			512			(96	)		0.69			0.87			(0.18	)
Dominion Energy(1)		348			356			(8	)		0.57			0.60			(0.03	)
Primary operating segments		988			1,125			(137	)		1.63			1.90			(0.27	)
Corporate and Other		(12	)		(176	)		164			(0.02	)		(0.30	)		0.28
Consolidated	$	976		$	949		$	27		$	1.61		$	1.60		$	0.01

(1) 2015 amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.

DVP

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

	Second Quarter							Year-To-Date
	2016		2015		% Change			2016		2015		% Change
Electricity delivered (million MWh)		18.9		20.1		(6	)%		40.1		43.0		(7	)%
Degree days (electric distribution service area):
Cooling		425		645		(34	)		429		645		(33	)
Heating		367		214		71			2,247		2,578		(13	)
Average electric distribution customer accounts (thousands)(1)		2,545		2,521		1			2,543		2,519		1

(1) Period average.

83

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

	Second Quarter 2016 vs. 2015 Increase (Decrease)						Year-To-Date 2016 vs. 2015 Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(11	)	$	(0.02	)	$	(26	)	$	(0.04	)
Other		—			—			(5	)		(0.01	)
FERC transmission equity return		10			0.02			21			0.04
Storm damage and service restoration		(10	)		(0.02	)		(12	)		(0.02	)
Other		(2	)		—			(11	)		(0.02	)
Share dilution		—			(0.01	)		—			(0.01	)
Change in net income contribution	$	(13	)	$	(0.03	)	$	(33	)	$	(0.06	)

Dominion Generation

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

	Second Quarter							Year-To-Date
	2016		2015		% Change			2016		2015		% Change
Electricity supplied (million MWh):
Utility		20.1		20.4		(1	)%		42.3		43.3		(2	)%
Merchant		6.2		6.6		(6	)		13.3		13.0		2
Degree days (electric utility service area):
Cooling		425		645		(34	)		429		645		(33	)
Heating		367		214		71			2,247		2,578		(13	)

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

	Second Quarter 2016 vs. 2015 Increase (Decrease)						Year-To-Date 2016 vs. 2015 Increase (Decrease)
	Amount			EPS			Amount			EPS
(millions, except EPS)
Regulated electric sales:
Weather	$	(23	)	$	(0.04	)	$	(54	)	$	(0.09	)
Other		5			0.01			2			—
Renewable energy investment tax credits(1)		(30	)		(0.05	)		(31	)		(0.05	)
Capacity related expenses		26			0.04			40			0.07
Outage costs		(24	)		(0.04	)		(23	)		(0.04	)
Merchant generation margin		(20	)		(0.03	)		(28	)		(0.05	)
Rate adjustment clause equity return		10			0.02			16			0.03
Other		(23	)		(0.04	)		(18	)		(0.03	)
Share dilution		—			(0.01	)		—			(0.02	)
Change in net income contribution	$	(79	)	$	(0.14	)	$	(96	)	$	(0.18	)

(1) Tax credit is reflected in Generation segment once project is placed into service.

84

Dominion Energy

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

	Second Quarter							Year-To-Date
	2016		2015		% Change			2016		2015		% Change
Gas distribution throughput (bcf):
Sales		3		3		—	%		16		19		(16	)%
Transportation		99		90		10			258		252		2
Heating degree days (gas distribution service area)		729		568		28			3,413		4,143		(18	)
Average gas distribution customer accounts (thousands)(1):
Sales		224		231		(3	)		233		239		(3	)
Transportation		1,079		1,069		1			1,073		1,065		1
Average retail energy marketing customer accounts (thousands)(1)		1,376		1,288		7			1,364		1,269		7

(1) Period average.

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

	Second Quarter 2016 vs. 2015 Increase (Decrease)					Year-To-Date 2016 vs. 2015 Increase (Decrease)
	Amount		EPS			Amount			EPS
(millions, except EPS)
Gas distribution margin:
Weather	$	1	$	—		$	(7	)	$	(0.01	)
Other		1		—			6			0.01
Assignment of shale development rights		21		0.04			(20	)		(0.03	)
Retail energy marketing operations		6		0.01			9			0.01
Other		4		—			4			—
Share dilution		—		(0.01	)		—			(0.01	)
Change in net income contribution	$	33	$	0.04		$	(8	)	$	(0.03	)

Corporate and Other

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

	Second Quarter									Year-To-Date
	2016			2015			$ Change			2016			2015			$ Change
(millions, except EPS)
Specific items attributable to operating segments	$	12		$	(17	)	$	29		$	(26	)	$	(62	)	$	36
Specific items attributable to corporate operations		(1	)		1			(2	)		(11	)		(2	)		(9	)
Total specific items		11			(16	)		27			(37	)		(64	)		27
Other corporate operations:
Renewable energy investment tax credits		51			4			47			132			10			122
Other		(47	)		(71	)		24			(107	)		(122	)		15
Total other corporate operations		4			(67	)		71			25			(112	)		137
Total net income (expense)	$	15		$	(83	)	$	98		$	(12	)	$	(176	)	$	164
EPS impact	$	0.02		$	(0.14	)	$	0.16		$	(0.02	)	$	(0.30	)	$	0.28

Total Specific Items

Corporate and Other includes specific items attributable to Dominion’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 19 to the Consolidated Financial Statements in this report for discussion of these items in more detail.

85

Virginia Power

Results of Operations

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

	Second Quarter						Year-To-Date
	2016		2015		$ Change		2016		2015		$ Change
(millions)
Net income	$	280	$	246	$	34	$	543	$	515	$	28

Overview

Second Quarter 2016 vs. 2015

Net income increased 14%, primarily due to the absence of charges related to ash pond and landfill closure costs at certain utility generation facilities, a decrease in capacity related expenses and an increase in rate adjustment clause revenue. These increases were partially offset by a decrease in sales to retail customers from a reduction in cooling degree days.

Year-To-Date 2016 vs. 2015

Net income increased 5%, primarily due to the absence of the write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015, a decrease in capacity related expenses and a decrease in charges related to ash pond and landfill closure costs at certain utility generation facilities. These increases were partially offset by a decrease in sales to retail customers from reductions in cooling and heating degree days.

Analysis of Consolidated Operations

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

	Second Quarter							Year-To-Date
	2016		2015		$ Change			2016		2015		$ Change
(millions)
Operating revenue	$	1,776	$	1,813	$	(37	)	$	3,666	$	3,950	$	(284	)
Electric fuel and other energy-related purchases		475		497		(22	)		1,011		1,307		(296	)
Purchased electric capacity		45		90		(45	)		113		184		(71	)
Net revenue		1,256		1,226		30			2,542		2,459		83
Other operations and maintenance		386		445		(59	)		836		841		(5	)
Depreciation and amortization		247		231		16			495		469		26
Other taxes		70		69		1			144		143		1
Other income		18		21		(3	)		34		36		(2	)
Interest and related charges		113		108		5			227		216		11
Income tax expense		178		148		30			331		311		20

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

Second Quarter 2016 vs. 2015

Net revenue increased 2%, primarily reflecting:

• A net decrease in capacity related expenses ($43 million);

• An increase from rate adjustment clauses ($33 million); and

• An increase in sales to customers due to the effect of changes in customer usage and other factors ($7 million); partially offset by

• A decrease in sales to retail customers from a reduction in cooling degree days ($58 million).

Other operations and maintenance decreased 13%, primarily reflecting:

• The absence of a $45 million charge related to ash pond and landfill closure costs at certain utility generation facilities; and

• A $10 million decrease in salaries, wages and benefits and general administrative expenses; partially offset by

• A $16 million increase in storm damage and service restoration costs.

Income tax expense increased 20%, primarily due to higher pre-tax income.

86

Year-To-Date 2016 vs. 2015

Net revenue increased 3%, primarily reflecting:

• The absence of an $85 million write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015;

• A net decrease in capacity related expenses ($66 million); and

• An increase from rate adjustment clauses ($51 million); partially offset by

• A decrease in sales to retail customers from a reduction in cooling and heating degree days ($132 million).

Other operations and maintenance decreased 1%, primarily reflecting:

• The absence of a $45 million charge related to ash pond and landfill closure costs at certain utility generation facilities;

• A $6 million decrease in certain electric transmission-related expenditures. These expenses are primarily recovered through state and FERC rates and do not impact net income; and

• A $6 million decrease in outside services; partially offset by

• Organizational design initiative costs ($32 million); and

• A $19 million increase in storm damage and service restoration costs.

Dominion Gas

Results of Operations

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

	Second Quarter						Year-To-Date
	2016		2015		$ Change		2016		2015		$ Change
(millions)
Net income	$	105	$	85	$	20	$	203	$	246	$	(43	)

Overview

Second Quarter 2016 vs. 2015

Net income increased 24%, primarily due to an increase in gains from agreements to convey shale development rights underneath several natural gas storage fields.

Year-To-Date 2016 vs. 2015

Net income decreased 17%, primarily due to a decrease in gas transportation and storage activities and a decrease 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 Gas’ results of operations:

	Second Quarter							Year-To-Date
	2016		2015		$ Change			2016		2015		$ Change
(millions)
Operating revenue	$	368	$	395	$	(27	)	$	799	$	926	$	(127	)
Purchased gas		16		21		(5	)		50		95		(45	)
Other energy-related purchases		1		7		(6	)		4		13		(9	)
Net revenue		351		367		(16	)		745		818		(73	)
Other operations and maintenance		74		124		(50	)		198		198		—
Depreciation and amortization		52		53		(1	)		95		104		(9	)
Other taxes		39		37		2			91		92		(1	)
Other income		9		4		5			15		13		2
Interest and related charges		23		18		5			45		35		10
Income tax expense		67		54		13			128		156		(28	)

An analysis of Dominion Gas’ results of operations follows:

Second Quarter 2016 vs. 2015

Net revenue decreased 4%, primarily reflecting:

• A $12 million decrease from regulated natural gas transmission operations, primarily reflecting:

• A $17 million decrease in gas transportation and storage activities, primarily due to decreased demand charges; and

87

• A $3 million decrease in NGL activities primarily due to decreased volumes; partially offset by

• An $8 million increase due to services performed for Atlantic Coast Pipeline; and

• A $5 million decrease from regulated natural gas distribution operations, primarily reflecting a decrease in rate adjustment clause revenue related to low income assistance programs ($7 million), partially offset by an increase in AMR and PIR program revenues ($2 million).

Other operations and maintenance decreased 40%, primarily reflecting:

• An increase in gains from agreements to convey shale development rights underneath several natural gas storage fields ($34 million);

• A decrease in bad debt expense at regulated natural gas distribution operations primarily related to low income assistance programs ($7 million). These bad debt expenses are recovered through rates and do not impact net income; and

• A $8 million decrease in salaries, wages and benefits and general administrative expenses; partially offset by

• An $8 million increase due to services performed for Atlantic Coast Pipeline. These expenses are billed to Atlantic Coast Pipeline and do not significantly impact net income.

Other income increased $5 million, primarily due to a gain on the sale of 0.65% of the non-controlling partnership interest in Iroquois.

Interest and related charges increased 28%, primarily due to higher interest expense on long-term debt resulting from a debt issuance in November 2015.

Income tax expense increased 24%, primarily reflecting higher pre-tax income.

Year-To-Date 2016 vs. 2015

Net revenue decreased 9%, primarily reflecting:

• An $38 million decrease from regulated natural gas distribution operations, primarily reflecting:

• A decrease in rate adjustment clause revenue related to low income assistance programs ($34 million); and

• A decrease in sales to customers due to a reduction in heating degree days ($6 million); partially offset by

• An increase in AMR and PIR program revenues ($7 million); and

• A $36 million decrease from regulated natural gas transmission operations, primarily reflecting:

• A $41 million decrease in gas transportation and storage activities, primarily due to decreased demand charges ($21 million), decreased regulated gas sales ($13 million) and decreased fuel retained ($10 million); and

• A $9 million decrease in NGL activities, due to decreased volumes ($7 million) and prices ($2 million); partially offset by

• A $15 million increase due to services performed for Atlantic Coast Pipeline.

Other operations and maintenance expense was $198 million for both the six months ended June 30, 2016 and 2015. These amounts reflect the impact of the following items:

• A decrease in bad debt expense at regulated natural gas distribution operations primarily related to low income assistance programs ($34 million). These bad debt expenses are recovered through rates and do not impact net income;

• A $9 million decrease in salaries, wages and benefits and general administrative expenses;

• A decrease in gains from agreements to convey shale development rights underneath several natural gas storage fields ($31 million);

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

• Organizational design initiative costs ($8 million).

Interest and related charges increased 29%, primarily due to higher interest expense on long-term debt resulting from a debt issuance in November 2015.

Income tax expense decreased 18%, primarily reflecting lower pre-tax income.

Liquidity and Capital Resources

Dominion 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.

88

In September 2015, Dominion initiated a program to purchase from the market up to $50 million of common units representing limited partner interests in Dominion Midstream. The common units may be acquired by Dominion over the 12 month period following commencement of the program at the discretion of management. During the six months ended June 30, 2016, Dominion purchased approximately 489,000 common units for $13 million. Dominion still has the ability to purchase $12 million of common units under the program.

Given the sufficiency of operating and other cash flows at the Dominion level, no dividends were declared or paid to Dominion by either Virginia Power or Dominion Gas during the first quarter of 2016. During the second quarter of 2016, no dividends were declared or paid to Dominion by Virginia Power.

At June 30 2016, Dominion had $2.0 billion of unused capacity under its credit facilities.

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

	2016			2015
(millions)
Cash and cash equivalents at January 1	$	607		$	318
Cash flows provided by (used in):
Operating activities		2,018			2,160
Investing activities		(3,725	)		(3,084	)
Financing activities		1,477			877
Net decrease in cash and cash equivalents		(230	)		(47	)
Cash and cash equivalents at June 30	$	377		$	271

Operating Cash Flows

Net cash provided by Dominion’s operating activities decreased $142 million, primarily due to higher net margin collateral requirements and the impact from unfavorable weather in 2016, partially offset by higher deferred fuel cost recoveries in its Virginia jurisdiction.

Dominion 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’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, 2015.

Credit Risk

Dominion’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’s credit exposure as of June 30, 2016 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)	$	87	$	31	$	56
Non-investment grade(2)		2		—		2
No external ratings:
Internally rated - investment grade(3)		11		—		11
Internally rated - non-investment grade(4)		11		1		10
Total	$	111	$	32	$	79

(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 63% of the total net credit exposure.

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

(3) The five largest counterparty exposures, combined, for this category represented approximately 11% of the total net credit exposure.

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

89

Investing Cash Flows

Net cash used in Dominion’s investing activities increased $641 million, primarily due to higher capital expenditures and the restricted cash for the Questar Combinations, partially offset by the absences of Dominion’s acquisition of DCG and the acquisition of solar development projects in 2015.

Financing Cash Flows and Liquidity

Dominion 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, 2015, the ability to borrow funds or issue securities and the return demanded by investors are affected by credit ratings. In addition, the raising of external capital is subject to certain regulatory requirements, including registration with the SEC for certain issuances.

Dominion 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 to use automatic shelf registration statements to register any offering of securities, other than those for exchange offers or business combination transactions.

Net cash provided by Dominion’s financing activities increased $600 million, primarily reflecting an increase in common stock issuances.

See Note 14 to the Consolidated Financial Statements in this report for further information regarding Dominion’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, 2015, there is a discussion on the use of capital markets by Dominion as well as the impact of credit ratings on the accessibility and costs of using these markets.

In March 2016, Fitch Ratings Ltd. and Standard & Poor’s changed the rating for Dominion’s junior subordinated debt securities to account for its inability to defer interest payments on the remarketed 2013 Series A RSNs. Junior subordinated debt securities with an interest deferral feature are rated one notch lower by Fitch Ratings Ltd. and Standard & Poor’s (BBB-) than junior subordinated debt securities without an interest deferral feature (BBB). See Note 14 to the Consolidated Financial Statements for a description of the remarketed notes. As of June 30, 2016, there have been no additional changes in Dominion’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, 2015, there is a discussion on the various covenants present in the enabling agreements underlying Dominion’s debt. As of June 30, 2016, there have been no material changes to debt covenants, nor any events of default under Dominion’s debt covenants. Pursuant to a waiver received in April 2016, the 65% maximum debt to total capital ratio in Dominion’s credit agreements will, with respect to Dominion only and upon closing of the Questar Combination, be temporarily increased to 70% until the end of the fourth fiscal quarter following closing (including the fiscal quarter in which the closing occurs).

Future Cash Payments for Contractual Obligations and Planned Capital Expenditures

As of June 30, 2016, there have been no material changes outside the ordinary course of business to Dominion’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, 2015.

Use of Off-Balance Sheet Arrangements

As of June 30, 2016, with the exception of the leasing arrangement described herein, 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, 2015.

Leasing Arrangement

In July 2016, Dominion signed an agreement with a lessor to construct and lease a new corporate office property in Richmond, Virginia. The lessor is providing equity and has obtained financing commitments from debt investors to fund the project costs, totaling $365 million. The project is expected to be completed by mid-2019. Dominion has been appointed to act as the

90

construction agent for the lessor, during which time Dominion will request cash draws from the the lessor and debt investors to fund all project costs. If the project is terminated under certain events of default, Dominion could be required to pay up to 89.9% of the then funded amount. For specific full recourse events, Dominion could be required to pay up to 100% of the then funded amount.

The five-year lease term will commence once construction is substantially complete and the facility is able to be occupied. At the end of the initial lease term, Dominion can (i) extend the term of the lease for an additional five years, subject to the approval of the participants, at current market terms, (ii) purchase the property for an amount equal to the project costs or, (iii) subject to certain terms and conditions, sell the property to a third party using commercially reasonable efforts to obtain the highest cash purchase price for the property. If the project is sold and the proceeds from the sale are insufficient to repay the investors for the project costs, Dominion may be required to make a payment to the lessor, up to 87% of project costs, for the difference between the project costs and sale proceeds.

The respective transactions have been structured so that Dominion is not considered the owner during construction for financial accounting purposes and, therefore, will not reflect the construction activity in its consolidated financial statements. The financial accounting treatment of the lease agreement will be impacted by the new accounting standard issued in February 2016. Dominion will be considered the owner of the leased property for tax purposes, and as a result, will be entitled to tax deductions for depreciation and interest expense.

Future Issues and Other Matters

The following discussion of future issues and other information includes current developments of previously disclosed matters and new issues arising during the period covered by, and subsequent to, the dates of Dominion’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, 2015 and Future Issues and Other Matters in MD&A in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2016.

Environmental Matters

Dominion 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, 2015, and Note 15 to the Consolidated Financial Statements in this report for additional information on various environmental matters.

In August 2015, the EPA issued final carbon standards for existing fossil fuel power plants. Known as the Clean Power Plan, the rule uses a set of measures for reducing emissions from existing sources that includes efficiency improvements at coal plants, displacing coal-fired generation with increased utilization of natural gas combined cycle units and expanding renewable resources. The new rule requires states to impose standards of performance limits for existing fossil fuel-fired electric generating units or equivalent statewide intensity-based or mass-based CO₂ binding goals or limits. States are required to submit interim plans to the EPA by September 2016 identifying how they will comply with the rule, with final plans due by September 2018. The EPA also proposed a federal plan and model trading rules that, when finalized, states can adopt or that would be put in place if, in response to the final guidelines, a state either does not submit a state plan or its plan is not approved by the EPA. Virginia Power’s most recent integrated resources plan filed in May 2016 includes four alternative plans that represent plausible compliance strategies with the rule as proposed, and which include additional coal unit retirements and additional low or zero-carbon resources. The final rule has been challenged in the United States Court of Appeals for the District of Columbia Circuit. In February 2016, the United States Supreme Court issued a stay of the Clean Power Plan until the disposition of the petitions challenging the rule now before the Court of Appeals, and, if such petitions are filed in the future, before the United States Supreme Court. Dominion does not know whether these legal challenges will impact the submittal deadlines for the state implementation plans. Also in February 2016, the Governor of Virginia announced that it will continue development of a state plan. Until all court challenges have been resolved, the state plans are developed and the EPA approves the plans, Dominion cannot predict the potential financial statement impacts. However, Dominion believes the potential expenditures to comply based on the four alternative plans discussed in the most recent integrated resources plan will be material.

Legal Matters

See Item 3. Legal Proceedings in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2015, Notes 12 and 15 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2016 and Notes 12 and 15 to the Consolidated Financial Statements and Item 1. Legal Proceedings in this report for additional information on various legal matters.

91

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, 2015, and Note 12 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2016 and in this report for additional information on various regulatory matters.

92

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’s and Virginia Power’s electric operations and Dominion’s and Dominion 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 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 Gas holds commodity-based financial derivative instruments held for non-trading purposes associated with purchases and sales of natural gas and other energy-related products.

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

A hypothetical 10% unfavorable change in commodity prices would have resulted in a decrease in fair value of $20 million and $24 million of Dominion’s commodity-based derivative instruments as of June 30, 2016 and December 31, 2015, respectively.

A hypothetical 10% decrease in commodity prices would have resulted in a decrease in the fair value of $54 million and $42 million of Virginia Power’s commodity-based derivative instruments as of June 30, 2016 and December 31, 2015, respectively.

A hypothetical 10% increase in commodity prices would have resulted in a decrease in fair value of $6 million and $5 million of Dominion Gas’ commodity-based derivative instruments as of June 30, 2016 and December 31, 2015, 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. Physical commodity-based derivative instruments will be recognized as a gross revenue or expense based upon the transaction price and volume.

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 the Companies, a hypothetical 10% increase in market interest rates would not have resulted in a material change in earnings at June 30, 2016 or December 31, 2015.

The Companies may also use forward-starting interest rate swaps and interest rate lock agreements as anticipatory hedges.

As of June 30, 2016, Dominion and Virginia Power had $3.1 billion and $1.8 billion, respectively, in aggregate notional amounts of these interest rate derivatives outstanding. A hypothetical 10% decrease in market interest rates would have resulted

93

in a decrease of $52 million and $42 million, respectively, in the fair value of Dominion’s and Virginia Power’s interest rate derivatives at June 30, 2016. As of December 31, 2015, Dominion, Virginia Power and Dominion Gas had $4.6 billion, $2.0 billion and $250 million, 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 $71 million, $52 million and $2 million, respectively, in the fair value of Dominion’s, Virginia Power’s and Dominion Gas’ interest rate derivatives at December 31, 2015.

In June 2016, Dominion Gas entered into foreign currency swaps with the purpose of hedging the foreign currency exchange risk associated with Euro denominated debt. As of June 30, 2016, Dominion Gas had $280 million (€250 million) in aggregate notional amounts of these foreign currency swaps outstanding. A hypothetical 10% increase in market interest rates would not have resulted in a material change in earnings at June 30, 2016.

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 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’s and Virginia Power’s Consolidated Balance Sheets at fair value.

Dominion recognized net realized gains (including investment income) on nuclear decommissioning and rabbi trust investments of $67 million and $102 million for the six months ended June 30, 2016 and 2015, respectively, and $184 million for the year ended December 31, 2015. 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 recorded in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $98 million for the six months ended June 30, 2016. Dominion recorded in AOCI and regulatory liabilities, a net decrease in unrealized gains on these investments of $62 million for the six months ended June 30, 2015 and $157 million for the year ended December 31, 2015.

Virginia Power recognized net realized gains (including investment income) on nuclear decommissioning trust investments of $32 million and $38 million for the six months ended June 30, 2016 and 2015, respectively, and $88 million for the year ended December 31, 2015. Net realized gains and losses include gains and losses from the sale of investments as well as any other-than-temporary declines in fair value. Virginia Power recorded in AOCI and regulatory liabilities, a net increase in unrealized gains on these investments of $53 million for the six months ended June 30, 2016. Virginia Power recorded in AOCI and regulatory liabilities, a net decrease in unrealized gains on these investments of $21 million for the six months ended June 30, 2015 and $76 million for the year ended December 31, 2015.

Dominion sponsors pension and other postretirement employee benefit plans that hold investments in trusts to fund employee benefit payments. Virginia Power and Dominion 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.

94

ITEM 4. CONTROLS AND PROCEDURES

Senior management of each of Dominion, Virginia Power, and Dominion Gas, including Dominion’s, Virginia Power’s, and Dominion 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’s, Virginia Power’s, and Dominion 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’s, Virginia Power’s, or Dominion 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.

95

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.

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, 2015.

• Notes 12 and 15 to the Consolidated Financial Statements in the Companies’ Quarterly Report on Form 10-Q for the quarter ended March 31, 2016.

• Notes 12 and 15 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, 2015, 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, 2015. For other factors that may cause actual results to differ materially from those indicated in any forward-looking statement or projection contained in this report, see Forward-Looking Statements in MD&A in this report.

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

Dominion

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)
4/1/16-4/30/16		1,639	$	75.39		—	19,629,059 shares/ $1.18 billion
5/1/16-5/31/16		6,739		71.47		—	19,629,059 shares/ $1.18 billion
6/1/16-6/30/16		1,527		71.68		—	19,629,059 shares/ $1.18 billion
Total		9,905	$	72.15		—	19,629,059 shares/ $1.18 billion

(1) In April, May and June 2016, 1,639 shares, 6,739 shares and 1,527 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 Board of Directors in February 2005, as modified in June 2007. The aggregate authorization granted by the Dominion 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.

96

ITEM 6. EXHIBITS

Exhibit Number	Description	Dominion	Virginia Power	Dominion Gas
3.1.a	Dominion Resources, Inc. Articles of Incorporation as amended and restated, effective May 20, 2010 (Exhibit 3.1, Form 8-K filed May 20, 2010, 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 Gas Holdings, LLC (Exhibit 3.1, Form S-4 filed April 4, 2014, File No. 333-195066).			X
3.2.a	Dominion Resources, Inc. Amended and Restated Bylaws, effective December 17, 2015 (Exhibit 3.1, Form 8-K filed December 17, 2015, 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 Gas Holdings, LLC dated as of September 12, 2013 (Exhibit 3.2, Form S-4 filed April 4, 2014, File No. 333-195066).			X
4	Dominion Resources, Inc., Virginia Electric and Power Company and Dominion 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 either of their total consolidated assets.	X	X	X
4.1	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); First Supplemental Indenture, dated as of October 1, 2013 (Exhibit 4.2, 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 (filed herewith); Ninth Supplemental Indenture, dated as of June 1, 2016 (filed herewith); Tenth Supplemental Indenture, dated as of June 1, 2016 (filed herewith).	X		X
4.2	Junior Subordinated Indenture II, dated June 1, 2006, between Dominion Resources, Inc. and The Bank of New York Mellon (successor to JPMorgan Chase Bank, N.A.), as Trustee (Exhibit 4.1, Form 10-Q for the quarter ended June 30, 2006 filed August 3, 2006, File No. 1-8489); First Supplemental Indenture dated as of June 1, 2006 (Exhibit 4.2, Form 10-Q for the quarter ended June 30, 2006 filed August 3, 2006, File No. 1-8489); Second Supplemental Indenture, dated as of September 1, 2006 (Exhibit 4.2, Form 10-Q for the quarter ended September 30, 2006 filed November 1, 2006, File No. 1-8489); Fourth Supplemental Indenture, dated as of June 1, 2013 (Exhibit 4.3, Form 8-K filed June 7, 2013, File No. 1-8489); Fifth Supplemental Indenture, dated as of June 1, 2013 (Exhibit 4.4, Form 8-K filed June 7, 2013, File No. 1-8489); Sixth Supplemental Indenture, dated as of June 1, 2014 (Exhibit 4.3, Form 8-K filed July 1, 2014, File No. 1-8489); Seventh Supplemental Indenture, dated as of September 1, 2014 (Exhibit 4.3, Form 8-K filed October 3, 2013, File No. 1-8489); Eighth Supplemental Indenture, dated March 7, 2016 (Exhibit 4.4, Form 8-K filed March 7, 2016, File No. 1-8489); Ninth Supplemental Indenture, dated May 26, 2016 (Exhibit 4.4, Form 8-K filed May 26, 2016, File No. 1-8489); Tenth Supplemental Indenture, dated as of July 1, 2016 (Exhibit 4.3, Form 8-K filed July 19, 2016, File No. 1-8489).	X
12.1	Ratio of earnings to fixed charges for Dominion Resources, Inc. (filed herewith).	X

97

Exhibit Number	Description	Dominion	Virginia Power	Dominion Gas
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 Gas Holdings, LLC (filed herewith).			X
31.a	Certification by Chief Executive Officer of Dominion Resources, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X
31.b	Certification by Chief Financial Officer of Dominion Resources, 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 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 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 Resources, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).	X
32.b	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Virginia Electric and Power Company as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).		X
32.c	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion 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 Resources, Inc.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, filed on August 3, 2016, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statement of Equity, (iv) Consolidated Statements of Comprehensive Income, (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 and Dominion Gas Holdings, LLC’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, filed on August 3, 2016, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Comprehensive Income, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.	X	X	X

* Indicates management contract or compensatory plan or arrangement

98

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 RESOURCES, INC. Registrant
August 3, 2016	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer
	VIRGINIA ELECTRIC AND POWER COMPANY Registrant
August 3, 2016	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer
	DOMINION GAS HOLDINGS, LLC Registrant
August 3, 2016	/s/ Michele L. Cardiff
	Michele L. Cardiff Vice President, Controller and Chief Accounting Officer

99

EXHIBIT INDEX

Exhibit Number	Description	Dominion	Virginia Power	Dominion Gas
3.1.a	Dominion Resources, Inc. Articles of Incorporation as amended and restated, effective May 20, 2010 (Exhibit 3.1, Form 8-K filed May 20, 2010, 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 Gas Holdings, LLC (Exhibit 3.1, Form S-4 filed April 4, 2014, File No. 333-195066).			X
3.2.a	Dominion Resources, Inc. Amended and Restated Bylaws, effective December 17, 2015 (Exhibit 3.1, Form 8-K filed December 17, 2015, 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 Gas Holdings, LLC dated as of September 12, 2013 (Exhibit 3.2, Form S-4 filed April 4, 2014, File No. 333-195066).			X
4	Dominion Resources, Inc., Virginia Electric and Power Company and Dominion 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 either of their total consolidated assets.	X	X	X
4.1	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); First Supplemental Indenture, dated as of October 1, 2013 (Exhibit 4.2, 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 (filed herewith); Ninth Supplemental Indenture, dated as of June 1, 2016 (filed herewith); Tenth Supplemental Indenture, dated as of June 1, 2016 (filed herewith).	X		X
4.2	Junior Subordinated Indenture II, dated June 1, 2006, between Dominion Resources, Inc. and The Bank of New York Mellon (successor to JPMorgan Chase Bank, N.A.), as Trustee (Exhibit 4.1, Form 10-Q for the quarter ended June 30, 2006 filed August 3, 2006, File No. 1-8489); First Supplemental Indenture dated as of June 1, 2006 (Exhibit 4.2, Form 10-Q for the quarter ended June 30, 2006 filed August 3, 2006, File No. 1-8489); Second Supplemental Indenture, dated as of September 1, 2006 (Exhibit 4.2, Form 10-Q for the quarter ended September 30, 2006 filed November 1, 2006, File No. 1-8489); Fourth Supplemental Indenture, dated as of June 1, 2013 (Exhibit 4.3, Form 8-K filed June 7, 2013, File No. 1-8489); Fifth Supplemental Indenture, dated as of June 1, 2013 (Exhibit 4.4, Form 8-K filed June 7, 2013, File No. 1-8489); Sixth Supplemental Indenture, dated as of June 1, 2014 (Exhibit 4.3, Form 8-K filed July 1, 2014, File No. 1-8489); Seventh Supplemental Indenture, dated as of September 1, 2014 (Exhibit 4.3, Form 8-K filed October 3, 2013, File No. 1-8489); Eighth Supplemental Indenture, dated March 7, 2016 (Exhibit 4.4, Form 8-K filed March 7, 2016, File No. 1-8489); Ninth Supplemental Indenture, dated May 26, 2016 (Exhibit 4.4, Form 8-K filed May 26, 2016, File No. 1-8489); Tenth Supplemental Indenture, dated as of July 1, 2016 (Exhibit 4.3, Form 8-K filed July 19, 2016, File No. 1-8489).	X
12.1	Ratio of earnings to fixed charges for Dominion Resources, Inc. (filed herewith).	X

100

Exhibit Number	Description	Dominion	Virginia Power	Dominion Gas
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 Gas Holdings, LLC (filed herewith).			X
31.a	Certification by Chief Executive Officer of Dominion Resources, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).	X
31.b	Certification by Chief Financial Officer of Dominion Resources, 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 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 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 Resources, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).	X
32.b	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Virginia Electric and Power Company as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).		X
32.c	Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion 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 Resources, Inc.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, filed on August 3, 2016, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statement of Equity, (iv) Consolidated Statements of Comprehensive Income, (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 and Dominion Gas Holdings, LLC’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2016, filed on August 3, 2016, formatted in XBRL: (i) Consolidated Statements of Income, (ii) Consolidated Balance Sheets, (iii) Consolidated Statements of Comprehensive Income, (iv) Consolidated Statements of Cash Flows, and (v) the Notes to Consolidated Financial Statements.	X	X	X

* Indicates management contract or compensatory plan or arrangement

101

EX-4.1.A

Exhibit 4.1.a

DOMINION GAS HOLDINGS, LLC

as Issuer,

and

DEUTSCHE BANK TRUST COMPANY AMERICAS

as Trustee,

Eighth Supplemental Indenture

Dated as of May 1, 2016

$150,000,000

2016 Series A 3.80% Senior Notes

due 2031

TABLE OF CONTENTS^*

ARTICLE I         2016 SERIES A 3.80% SENIOR NOTES DUE 2031			1
	Section 101.	Establishment	1
	Section 102.	Definitions	2
	Section 103.	Payment of Principal and Interest	4
	Section 104.	Denominations	5
	Section 105.	Global Securities	5
	Section 106.	Redemption	6
	Section 107.	Sinking Fund; Conversion	7
	Section 108.	Additional Interest	7
	Section 109.	Paying Agent	7
ARTICLE II       MISCELLANEOUS PROVISIONS			8
	Section 201.	Ratification and Incorporation of Base Indenture	8
	Section 202.	Executed in Counterparts	8
	Section 203.	Assignment	8
	Section 204.	Trustee’s Disclaimer	8

^*  This Table of Contents does not constitute part of the Indenture or have any bearing upon the interpretation of any of its terms and provisions.

THIS EIGHTH SUPPLEMENTAL INDENTURE is made as of the 1st day of May, 2016, by and between DOMINION GAS HOLDINGS, LLC, a Virginia limited liability company, having its principal office at 120 Tredegar Street, Richmond, Virginia 23219 (the “Company”) and DEUTSCHE BANK TRUST COMPANY AMERICAS, a New York banking corporation, as Trustee, having a corporate trust office at 60 Wall Street, 16^th Floor, New York, New York 10005 (herein called the “Trustee”).

W I T N E S S E T H:

WHEREAS, the Company has heretofore entered into an Indenture dated as of October 1, 2013, between the Company and the Trustee (as amended, restated or otherwise modified, the “Base Indenture”) with respect to senior debt securities;

WHEREAS, the Base Indenture is incorporated herein by this reference and the Base Indenture, as heretofore supplemented, as further supplemented by this Eighth Supplemental Indenture, and as may be hereafter supplemented or amended from time to time, is herein called the “Indenture”;

WHEREAS, under the Base Indenture, a new series of Securities may at any time be established in accordance with the provisions of the Base Indenture and the terms of such series may be described by a supplemental indenture executed by the Company and the Trustee;

WHEREAS, the Company proposes to create under the Indenture a new series of Securities;

WHEREAS, additional Securities of other series hereafter established, except as may be limited in the Base Indenture as at the time supplemented and modified, may be issued from time to time pursuant to the Indenture as at the time supplemented and modified;

WHEREAS, all conditions necessary to authorize the execution and delivery of this Eighth Supplemental Indenture and to make it a valid and binding obligation of the Company have been done or performed.

NOW, THEREFORE, in consideration of the agreements and obligations set forth herein and for other good and valuable consideration, the sufficiency of which is hereby acknowledged, the parties hereto hereby agree as follows:

ARTICLE I

2016 SERIES A 3.80% SENIOR NOTES DUE 2031

Section 101. Establishment. There is hereby established a new series of Securities to be issued under the Indenture, to be designated as the Company’s 2016 Series A 3.80% Senior Notes due 2031 (the “Series A Senior Notes”).

1

There are to be authenticated and delivered $150,000,000 principal amount of Series A Senior Notes, and such principal amount of the Series A Senior Notes may be increased from time to time pursuant to the penultimate paragraph of Section 301 of the Base Indenture. All Series A Senior Notes need not be issued at the same time and such series may be reopened at any time, without the consent of any Holder, for issuances of additional Series A Senior Notes. Any such additional Series A Senior Notes will have the same interest rate, maturity and other terms as those initially issued. Further Series A Senior Notes may also be authenticated and delivered as provided by Sections 304, 305, 306, 905 or 1107 of the Base Indenture.

The Series A Senior Notes shall be issued as Registered Securities in global form without coupons, in substantially the form set out in Exhibit A hereto. The entire initially issued principal amount of the Series A Senior Notes shall initially be evidenced by one or more certificates which shall be deposited with, or on behalf of, Clearstream Banking, société anonyme (“Clearstream”) and Euroclear Bank S.A./N.V., as operator of the Euroclear system (“Euroclear”) and registered in the name of the Common Depositary or its nominee for, and in respect of interests held through, Clearstream and Euroclear.

The form of the Trustee’s Certificate of Authentication for the Series A Senior Notes shall be in substantially the form set forth in Exhibit B hereto.

Each Series A Senior Note shall be dated the date of authentication thereof and shall bear interest from the date of original issuance thereof or from the most recent Interest Payment Date to which interest has been paid or duly provided for.

Section 102. Definitions. The following defined terms used herein shall, unless the context otherwise requires, have the meanings specified below. Capitalized terms used herein for which no definition is provided herein shall have the meanings set forth in the Base Indenture. Unless the context otherwise requires, any reference to a “Section” refers to a Section of this Eighth Supplemental Indenture.

“Business Day” means any day that is not a Saturday or Sunday and that is not a day on which banking institutions are authorized or obligated by law or executive order to close in London, United Kingdom or New York, New York, and on which the Trans-European Automated Real-time Gross Settlement Express Transfer system (the TARGET2 system), or any successor thereto, operates.

“Common Depositary” means a depositary common to Clearstream and Euroclear, being initially Deutsche Bank AG, London Branch, until a successor Common Depositary, if any, shall have become such pursuant to this Indenture, and thereafter Common Depositary shall mean or include each Person who is then a Common Depositary hereunder.

“Comparable Treasury Issue” means the United States Treasury security selected by an Independent Investment Banker as having a maturity comparable to the remaining term of the Series A Senior Notes to be redeemed (assuming, for this purpose, that the Series A Senior Notes matured on April 23, 2031) that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term in years and months of the Series A Senior Notes.

2

“Comparable Treasury Price” for any Redemption Date means (i) the average of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (ii) if the Independent Investment Banker obtains fewer than five such Reference Treasury Dealer Quotations, the average of all such quotations.

“Independent Investment Banker” means Deutsche Bank Securities Inc. and its affiliates or successors or any other independent investment and banking institution of national standing appointed by the Company.

“Interest Payment Dates” means May 15 and November 15 of each year, commencing on November 15, 2016, provided that the final interest period shall run from November 15, 2030 to May 23, 2031, and the final interest payment date shall be May 23, 2031.

“Original Issue Date” means May 25, 2016.

“Outstanding,” when used with respect to the Series A Senior Notes, means, as of the date of determination, all Series A Senior Notes theretofore authenticated and delivered under the Indenture, except:

(i) Series A Senior Notes theretofore canceled by the Trustee or delivered to the Trustee for cancellation;

(ii) Series A Senior Notes for whose payment at the Maturity thereof money in the necessary amount has been theretofore deposited (other than pursuant to Section 402 of the Base Indenture) with the Trustee or any Paying Agent (other than the Company) in trust or set aside and segregated in trust by the Company (if the Company shall act as its own Paying Agent) for the Holders of such Series A Senior Notes, provided that, if such Series A Senior Notes are to be redeemed, notice of such redemption has been duly given pursuant to this Indenture or provision therefor satisfactory to the Trustee has been made;

(iii) Series A Senior Notes with respect to which the Company has effected defeasance or covenant defeasance pursuant to Section 402 of the Base Indenture, except to the extent provided in Section 402 of the Base Indenture; and

(iv) Series A Senior Notes that have been paid pursuant to Section 306 of the Base Indenture or in exchange for or in lieu of which other Series A Senior Notes have been authenticated and delivered pursuant to the Indenture, other than any such Series A Senior Notes in respect of which there shall have been presented to the Trustee proof satisfactory to it that such Series A Senior Notes are held by a bona fide purchaser in whose hands such Series A Senior Notes are valid obligations of the Company;

provided, however, that in determining whether the Holders of the requisite principal amount of Outstanding Series A Senior Notes have given any request, demand, authorization, direction, notice, consent or waiver under the Indenture or are present at a meeting of Holders of Series A Senior Notes for quorum purposes, Series A Senior Notes owned by the Company or any other obligor upon the Series A Senior Notes or any Affiliate of the Company or such other obligor shall be disregarded and deemed not to be Outstanding, except that, in determining whether the

3

Trustee shall be protected in making any such determination or relying upon any such request, demand, authorization, direction, notice, consent or waiver, only Series A Senior Notes which a Responsible Officer of the Trustee actually knows to be so owned shall be so disregarded. Series A Senior Notes so owned which shall have been pledged in good faith may be regarded as Outstanding if the pledgee establishes to the satisfaction of the Trustee (A) the pledgee’s right so to act with respect to such Series A Senior Notes and (B) that the pledgee is not the Company or any other obligor upon the Series A Senior Notes or an Affiliate of the Company or such other obligor.

“Primary Treasury Dealer” means a primary United States government securities dealer in the United States as designated by the Federal Reserve Bank of New York.

“Reference Treasury Dealer” means (i) Deutsche Bank Securities Inc. and its affiliates or successors; provided that, if any such firm or its successors ceases to be a Primary Treasury Dealer, the Company shall substitute another Primary Treasury Dealer; and (ii) up to four other Primary Treasury Dealers selected by the Company.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Independent Investment Banker, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Independent Investment Banker at 3:30 p.m., New York City time, on the third Business Day preceding such Redemption Date.

“Regular Record Date” means, with respect to each Interest Payment Date, the close of business on the Business Day preceding such Interest Payment Date; provided, that with respect to Series A Senior Notes that are not represented by one or more Global Securities, the Regular Record Date shall be the close of business on the 15th calendar day (whether or not a Business Day) preceding such Interest Payment Date.

“Securities Act” means the Securities Act of 1933, as amended.

“Stated Maturity” means May 23, 2031.

“Treasury Rate” means, with respect to any Redemption Date, the rate per annum equal to the semiannual equivalent yield to maturity or interpolated (on a day count basis) of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date.

The terms “Company,” “Trustee,” “Base Indenture,” and “Indenture” shall have the respective meanings set forth in the recitals to this Eighth Supplemental Indenture and the paragraph preceding such recitals.

Section 103. Payment of Principal and Interest. The principal of the Series A Senior Notes shall be due at the Stated Maturity (unless earlier redeemed). The unpaid principal amount of the Series A Senior Notes shall bear interest at the rate of 3.80% per annum until paid or duly provided for, such interest to accrue from the Original Issue Date or from the most recent Interest Payment Date to which interest has been paid or duly provided for. Interest shall be paid semi-annually

4

in arrears on each Interest Payment Date to the Person in whose name the Series A Senior Notes are registered on the Regular Record Date for such Interest Payment Date; provided that interest payable at the Stated Maturity of principal or on a Redemption Date as provided herein will be paid to the Person to whom principal is payable. Any such interest that is not so punctually paid or duly provided for will forthwith cease to be payable to the Holders on such Regular Record Date and may either be paid to the Person or Persons in whose name the Series A Senior Notes are registered at the close of business on a Special Record Date for the payment of such defaulted interest to be fixed by the Trustee (in accordance with Section 307 of the Base Indenture), notice whereof shall be given to Holders of the Series A Senior Notes not less than ten (10) days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange, if any, on which the Series A Senior Notes may be listed, and upon such notice as may be required by any such exchange, all as more fully provided in the Base Indenture.

Payments of interest on the Series A Senior Notes will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the Series A Senior Notes shall be computed and paid on the basis of a 360-day year of twelve 30-day months. In the event that any date on which interest is payable on the Series A Senior Notes is not a Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Payment of the principal and interest on the Series A Senior Notes shall be made at the office of an Affiliate of the Trustee in London, United Kingdom, as designated in writing from time to time by the Trustee, in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts, with any such payment that is due at the Stated Maturity of any Series A Senior Notes, upon redemption or repurchase being made upon surrender of such Series A Senior Notes to the Paying Agent; provided that payments of interest (including interest on any Interest Payment Date) will be made, subject to such surrender where applicable, at the option of the Company, (i) by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (ii) by wire transfer at such place and to such account at a banking institution as may be designated in writing to the Company and the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto. In the event that any date on which principal and interest is payable on the Series A Senior Notes is not a Business Day, then payment of the principal and interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Section 104. Denominations. The Series A Senior Notes may be issued in denominations of $200,000, or any greater integral multiple of $1,000.

Section 105. Global Securities. The Series A Senior Notes will be initially issued in the form of one or more Global Securities registered in the name of the Common Depositary or its nominee. Except under the limited circumstances described below, Series A Senior Notes represented by such Global Securities will not be exchangeable for, and will not otherwise be issuable as, Series A Senior Notes in definitive form registered in names other than the Common Depositary or its nominee. The Global Securities described above may not be transferred except

5

by the Common Depositary to a nominee of the Common Depositary or by a nominee of the Common Depositary to the Common Depositary or another nominee of the Common Depositary or to a successor Common Depositary or its nominee.

Owners of beneficial interests in such a Global Security will not be considered the Holders thereof for any purpose under the Indenture, and no Global Security representing a Series A Senior Note shall be exchangeable, except for another Global Security of like denomination and tenor to be registered in the name of the Common Depositary or its nominee or to a successor Common Depositary or its nominee or except as described below. The rights of Holders of such Global Security shall be exercised only through the Common Depositary.

A Global Security shall be exchangeable for Series A Senior Notes registered in the names of persons other than the Common Depositary or its nominee only if (i) Clearstream, Euroclear or any successor thereto notifies the Company that it is no longer willing or able to act as a clearing system for the Global Securities, or (ii) the Company determines, in its sole discretion, not to have the Series A Senior Notes represented by a Global Security. Certificated Notes issued in exchange for Global Securities, any beneficial interest therein or any portion thereof shall be registered in the names, and issued in any approved denominations, requested by or on behalf of the Common Depositary (in accordance with its customary procedures).

Section 106. Redemption. Prior to April 23, 2031, the Series A Senior Notes are redeemable, in whole or in part at any time and from time to time at the option of the Company, at a Redemption Price equal to the greater of:

(i) 100% of the principal amount of Series A Senior Notes then Outstanding to be so redeemed, or

(ii) the sum of the present values of the remaining scheduled payments of principal and interest on the Series A Senior Notes to be redeemed that would be due if such Series A Senior Notes matured on April 23, 2031 but for the redemption (not including any portion of such payments of interest accrued as of the Redemption Date) discounted to the Redemption Date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate, plus 35 basis points, as calculated by an Independent Investment Banker,

plus, in either of the above cases, accrued and unpaid interest thereon to the Redemption Date.

On or after April 23, 2031, the Series A Senior Notes are redeemable, in whole or in part, at any time and from time to time at the option of the Company, at a Redemption Price equal to 100% of the principal amount of Series A Senior Notes then Outstanding to be so redeemed, plus accrued and unpaid interest thereon to the Redemption Date.

The Treasury Rate shall be calculated no later than the third Business Day preceding the Redemption Date.

Unless the Company defaults in the payment of the Redemption Price, on and after the Redemption Date, interest will cease to accrue on the Series A Senior Notes or portions thereof called for redemption.

6

In the event of the redemption of the Series A Senior Notes in part only, a new Series A Senior Note or Notes for the unredeemed portion will be issued in the name or names of the Holders thereof upon surrender thereof.

In the case of a partial redemption, no such partial redemption shall reduce the portion of the principal amount of a Series A Senior Note not redeemed to less than $200,000.

The Company shall notify the Trustee of the Redemption Price in writing promptly after the calculation thereof and the Trustee shall have no responsibility for such calculation. The notice of redemption shall be sent in accordance with the terms of the Base Indenture.

Section 107. Sinking Fund; Conversion. The Series A Senior Notes shall not have a sinking fund. The Series A Senior Notes are not convertible into or exchangeable for Equity Securities or any other securities.

Section 108. Additional Interest on Overdue Amounts. Any principal of and installment of interest on the Series A Senior Notes that is overdue shall bear interest at the rate of 3.80% per annum (to the extent that the payment of such interest shall be legally enforceable), from the dates such amounts are due until they are paid or made available for payment, and such interest shall be payable on demand.

Section 109. Paying Agent and Place of Payment. The Trustee shall initially serve as Paying Agent with respect to the Series A Senior Notes. The Place of Payment for the Series A Senior Notes issued hereunder shall be the office of an Affiliate of the Trustee in London, United Kingdom, as designated in writing from time to time by the Trustee. In addition, the Company undertakes that, to the extent permitted by law, the Company will, for as long as Series A Senior Notes issued hereunder remain Outstanding, use its commercially reasonable efforts to maintain a Place of Payment in a Member State of the European Union (if any) that will not be required to withhold or deduct tax pursuant to European Council Directive 2003/48/EC or any other Directive implementing the conclusions of the ECOFIN Council meeting of November 26-27, 2000 or any law implementing or complying with, or introduced to conform to, such Directive.

7

ARTICLE II

MISCELLANEOUS PROVISIONS

Section 201. Ratification and Incorporation of Base Indenture. As supplemented hereby, the Base Indenture is in all respects ratified and confirmed by the Company, and the Base Indenture and this Eighth Supplemental Indenture shall be read, taken and construed as one and the same instrument.

Section 202. Executed in Counterparts. This Eighth Supplemental Indenture may be executed in several counterparts, each of which shall be deemed to be an original, and such counterparts shall together constitute but one and the same instrument. The exchange of copies of this Eighth Supplemental Indenture and of signature pages by facsimile or PDF transmission shall constitute effective execution and delivery of this Eighth Supplemental Indenture as to the parties hereto and may be used in lieu of the original manually executed Eighth Supplemental Indenture for all purposes. Signatures of the parties hereto transmitted by facsimile or PDF shall be deemed to be their original signatures for all purposes.

Section 203. Assignment. The Company shall have the right at all times to assign any of its rights or obligations under the Indenture with respect to the Series A Senior Notes to a direct or indirect wholly-owned subsidiary of the Company; provided that, in the event of any such assignment, the Company shall remain primarily liable for the performance of all such obligations. The Indenture may also be assigned by the Company in connection with a transaction described in Article Eight of the Base Indenture.

Section 204. Trustee’s Disclaimer. All of the provisions contained in the Base Indenture in respect of the rights, powers, privileges, protections, duties and immunities of the Trustee, including without limitation its right to be indemnified, shall be applicable in respect of the Series A Senior Notes and of this Eighth Supplemental Indenture as fully and with like effect as if set forth herein in full. The Trustee accepts the amendments of the Indenture effected by this Eighth Supplemental Indenture, but on the terms and conditions set forth in the Indenture, including the terms and provisions defining and limiting the liabilities and responsibilities of the Trustee. Without limiting the generality of the foregoing, the Trustee shall not be responsible in any manner whatsoever for or with respect to any of the recitals or statements contained herein, all of which recitals or statements are made solely by the Company, or for or with respect to (i) the validity or sufficiency of this Eighth Supplemental Indenture or any of the terms or provision hereof, (ii) the proper authorization hereof by the Company by action or otherwise, (iii) the due execution hereof by the Company, or (iv) the consequences of any amendment herein provided for, and the Trustee makes no representation with respect to any such matters.

[Signature Page Follows]

8

IN WITNESS WHEREOF, each party hereto has caused this instrument to be signed in its name and behalf by its duly authorized officer, all as of the day and year first above written.

DOMINION GAS HOLDINGS, LLC
By:	/s/ James R. Chapman
Name:	James R. Chapman
Title:	Senior Vice President – Mergers & Acquisitions and Treasurer
DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:	/s/ Carol Ng
Name:	Carol Ng
Title:	Vice President
By:	/s/ Deirdra N. Ross
Name:	Deirdra N. Ross
Title:	Vice President

9

EXHIBIT A

FORM OF

2016 SERIES A 3.80% SENIOR NOTE

DUE 2031

[UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF DEUTSCHE BANK AG, LONDON BRANCH AS COMMON DEPOSITARY FOR CLEARSTREAM BANKING, SOCIÉTÉ ANONYME, LUXEMBOURG, AND EUROCLEAR BANK SA/NV, AS OPERATOR OF THE EUROCLEAR SYSTEM (THE “COMMON DEPOSITARY”), TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF BT GLOBENET NOMINEES LIMITED OR SUCH OTHER NAME AS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE COMMON DEPOSITARY AND ANY PAYMENT IS MADE TO BT GLOBENET NOMINEES LIMITED OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE COMMON DEPOSITORY, ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL SINCE THE REGISTERED OWNER HEREOF, BT GLOBENET NOMINEES LIMITED, HAS AN INTEREST HEREIN.]**

[THIS SERIES A SENIOR NOTE IS A GLOBAL SECURITY WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF BT GLOBENET NOMINEES LIMITED. THIS SERIES A SENIOR NOTE MAY NOT BE EXCHANGED IN WHOLE OR IN PART FOR A SECURITY REGISTERED, AND NO TRANSFER OF THIS SERIES A SENIOR NOTE IN WHOLE OR IN PART MAY BE REGISTERED, IN THE NAME OF ANY PERSON OTHER THAN SUCH COMMON DEPOSITARY OR A NOMINEE THEREOF, EXCEPT IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE. EVERY SERIES A SENIOR NOTE AUTHENTICATED AND DELIVERED UPON REGISTRATION OF, TRANSFER OF, OR IN EXCHANGE FOR OR IN LIEU OF, THIS SERIES A SENIOR NOTE SHALL BE A GLOBAL SECURITY SUBJECT TO THE FOREGOING, EXCEPT IN SUCH LIMITED CIRCUMSTANCES.]**

THIS SECURITY HAS NOT BEEN REGISTERED UNDER THE U.S. SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), OR THE SECURITIES LAWS OF ANY STATE OR OTHER JURISDICTION. NEITHER THIS SECURITY NOR ANY INTEREST OR PARTICIPATION HEREIN MAY BE REOFFERED, SOLD, ASSIGNED, TRANSFERRED, PLEDGED, ENCUMBERED OR OTHERWISE DISPOSED OF IN THE ABSENCE OF SUCH REGISTRATION OR UNLESS SUCH TRANSACTION IS EXEMPT FROM, OR NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE U.S. SECURITIES ACT.

THE HOLDER OF THIS SECURITY, BY ITS ACCEPTANCE HEREOF, AGREES ON ITS OWN BEHALF AND ON BEHALF OF ANY INVESTOR FOR WHICH IT HAS PURCHASED SECURITIES TO OFFER, SELL OR OTHERWISE TRANSFER SUCH

** Insert in Global Securities.

A-1

SECURITY, PRIOR TO THE DATE WHICH IS 40 DAYS AFTER THE LATER OF THE ORIGINAL ISSUE DATE HEREOF AND THE DATE ON WHICH THE SECURITY (OR ANY PREDECESSOR OF THIS SECURITY) WAS FIRST OFFERED TO PERSONS OTHER THAN DISTRIBUTORS (AS DEFINED IN RULE 902 OF REGULATION S) IN RELIANCE ON REGULATION S, ONLY (A) TO THE ISSUER, (B) PURSUANT TO A REGISTRATION STATEMENT WHICH HAS BEEN DECLARED EFFECTIVE UNDER THE U.S. SECURITIES ACT, (C) PURSUANT TO OFFERS AND SALES THAT OCCUR OUTSIDE THE UNITED STATES IN COMPLIANCE WITH THE U.S. SECURITIES ACT, OR (D) PURSUANT TO ANY OTHER AVAILABLE EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE U.S. SECURITIES ACT, SUBJECT IN EACH OF THE FOREGOING CASES TO ANY REQUIREMENT OF LAW THAT THE DISPOSITION OF ITS PROPERTY OR THE PROPERTY OF SUCH INVESTOR ACCOUNT OR ACCOUNTS BE AT ALL TIMES WITHIN ITS OR THEIR CONTROL AND IN COMPLIANCE WITH ANY APPLICABLE STATE SECURITIES LAWS; AND ANY APPLICABLE LOCAL LAWS AND REGULATIONS.

THE HOLDER OF THIS NOTE, BY ITS ACCEPTANCE HEREOF, AGREES ON ITS OWN BEHALF AND ON BEHALF OF ANY INVESTOR ACCOUNT FOR WHICH IT HAS PURCHASED SECURITIES THAT IT SHALL NOT TRANSFER THE SECURITIES IN AN AMOUNT LESS THAN $200,000.

DOMINION GAS HOLDINGS, LLC

$150,000,000

2016 SERIES A 3.80% SENIOR NOTE

DUE 2031

No. R-             ISIN No. XS1418789563

Euroclear and Clearstream Common Code No. 141878956

Dominion Gas Holdings, LLC, a limited liability company duly organized and existing under the laws of Virginia (herein called the “Company,” which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to BT Globenet Nominees Limited**, or registered assigns (the “Holder”), the principal sum of One Hundred Fifty Million Dollars ($150,000,000) on May 23, 2031 and to pay interest thereon from May 25, 2016 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually in arrears on May 15 and November 15 of each year, commencing on November 15, 2016, with the final Interest Payment Date being May 23, 2031, at the rate of 3.80% per annum, until the principal hereof is paid or made available for payment, provided that any principal, and any such installment of interest, that is overdue shall bear interest at the rate of 3.80% per annum (to the extent that the payment of such interest shall be legally enforceable), from the dates such amounts are due until they are paid or made available for payment, and such interest shall be payable on demand. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in such Indenture, be paid to the Person in whose name this Series A Senior Note (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date for such

A-2

interest; provided that the interest payable at Stated Maturity or on a Redemption Date will be paid to the Person to whom principal is payable. The Regular Record Date shall be the close of business on the Business Day preceding such Interest Payment Date; provided, that with respect to Series A Senior Notes that are not represented by one or more Global Securities, the Regular Record Date shall be the close of business on the 15th calendar day (whether or not a Business Day) preceding such Interest Payment Date. Any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Series A Senior Note (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Series A Senior Notes not less than 10 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Series A Senior Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.

Payments of interest on the Series A Senior Notes will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the Series A Senior Notes shall be computed and paid on the basis of a 360-day year of twelve 30-day months. In the event that any date on which interest is payable on the Series A Senior Notes is not a Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Payment of the principal of and interest on this Series A Senior Note will be made at the office of an Affiliate of the Trustee in London, United Kingdom, as designated in writing from time to time by the Trustee, in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts, with any such payment that is due at the Stated Maturity of any Series A Senior Note, upon redemption or repurchase being made upon surrender of such Series A Senior Note to such office or agency; provided, however, that at the option of the Company payment of interest, subject to such surrender where applicable, may be made (i) by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (ii) by wire transfer at such place and to such account at a banking institution as may be designated in writing to the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto.

Reference is hereby made to the further provisions of this Series A Senior Note set forth on the reverse hereof, which further provisions shall for all purposes have the same effect as if set forth at this place.

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse hereof by manual signature, this Series A Senior Note shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

A-3

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

Dated:	DOMINION GAS HOLDINGS, LLC
	By:
	Name:
	Title:

A-4

[REVERSE OF 2016 SERIES A 3.80% SENIOR NOTE]

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture dated as of October 1, 2013 (the “Base Indenture”), as heretofore supplemented and as further supplemented by a Eighth Supplemental Indenture dated as of May 1, 2016 (the “Eighth Supplemental Indenture” and together with the Base Indenture, as it may be hereafter supplemented or amended from time to time, the “Indenture,” which term shall have the meaning assigned to it in such instrument), by and between the Company and Deutsche Bank Trust Company Americas, as Trustee (the “Trustee”), and reference is hereby made to the Indenture for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities and of the terms upon which the Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof (the “Series A Senior Notes”) which is unlimited in aggregate principal amount.

The Series A Senior Notes are redeemable, in whole or in part, at any time and from time to time in the manner and with the effect provided in the Indenture.

If an Event of Default with respect to Series A Senior Notes shall occur and be continuing, the principal of the Series A Senior Notes may be declared due and payable in the manner and with the effect provided in the Indenture.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected under the Indenture at any time by the Company and the Trustee for the series of Securities affected, with the consent of the Holders of a majority in principal amount of the Securities at the time Outstanding of each series to be affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Series A Senior Note shall be conclusive and binding upon such Holder and upon all future Holders of this Series A Senior Note and of any Series A Senior Note issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Series A Senior Note.

As provided in and subject to the provisions of the Indenture, the Holder of this Series A Senior Note shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Series A Senior Notes, the Holders of not less than a majority in principal amount of the Series A Senior Notes at the time Outstanding shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee indemnity or security reasonably satisfactory to it, and the Trustee shall not have received from the Holders of a majority in principal amount of Series A Senior Notes at the time Outstanding a direction inconsistent with such request, and shall have failed to institute any such proceeding for 60 days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Series A Senior Note for the enforcement of any payment of principal hereof or premium, if any, or interest hereon on or after the respective due dates expressed or provided for herein.

A-5

No reference herein to the Indenture and no provision of this Series A Senior Note or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of, premium, if any, and interest on this Series A Senior Note at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Series A Senior Note is registrable in the Security Register, upon surrender of this Series A Senior Note for registration of transfer at the office or agency of the Company in any place where the principal of, premium, if any, and interest on this Series A Senior Note are payable, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Series A Senior Notes of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

The Series A Senior Notes are issuable only in registered form without coupons in denominations of $200,000 or any greater integral multiple of $1,000. As provided in the Indenture and subject to certain limitations therein set forth, Series A Senior Notes are exchangeable for a like aggregate principal amount of Series A Senior Notes having the same Stated Maturity and of like tenor of any authorized denominations as requested by the Holder upon surrender of the Series A Senior Note or Series A Senior Notes to be exchanged at the office or agency of the Company.

No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Series A Senior Note for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Series A Senior Note be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

All terms used in this Series A Senior Note that are defined in the Indenture shall have the meanings assigned to them in the Indenture.

A-6

ABBREVIATIONS

The following abbreviations, when used in the inscription on the face of this instrument, shall be construed as though they were written out in full according to applicable laws or regulations:

TEN COM -	as tenants in common
TEN ENT -	as tenants by the entireties
JT TEN -	as joint tenants with rights of survivorship and not as tenants in common
UNIF GIFT MIN ACT -	Custodian for
	(Cust)
	(Minor)
	Under Uniform Gifts to Minors Act of
	(State)

Additional abbreviations may also be used though not on the above list.

A-7

FOR VALUE RECEIVED, the undersigned hereby sell(s) and transfer(s) unto

.

(please insert Social Security or other identifying number of assignee)

.

.

.

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE OF ASSIGNEE

the within Series A Senior Note and all rights thereunder, hereby irrevocably constituting and appointing

.

.

.

.

.

.

agent to transfer said Series A Senior Note on the books of the Company, with full power of substitution in the premises.

Dated:                                        ,                 

NOTICE: The signature to this assignment must correspond with the name as written upon the face of the within instrument in every particular without alteration or enlargement, or any change whatever.

A-8

EXHIBIT B

CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:
	Authorized Signatory
Dated:

B-1

EX-4.1.B

Exhibit 4.1.b

DOMINION GAS HOLDINGS, LLC,

as Issuer,

and

DEUTSCHE BANK TRUST COMPANY AMERICAS,

as Trustee.

Ninth Supplemental Indenture

Dated as of June 1, 2016

€250,000,000

2016 Series B 1.45% Senior Notes

due 2026

TABLE OF CONTENTS¹

			Page
ARTICLE I 2016 SERIES B 1.45% SENIOR NOTES DUE 2026				1
	Section 101.	Establishment.		1
	Section 102.	Definitions.		2
	Section 103.	Payment of Principal and Interest.		5
	Section 104.	Denominations.		6
	Section 105.	Global Securities.		6
	Section 106.	Optional Redemption.		7
	Section 107.	Tax Redemption.		8
	Section 108.	Additional Amounts.		8
	Section 109.	Sinking Fund; Conversion.		10
	Section 110.	Additional Interest on Overdue Amounts.		10
	Section 111.	Paying Agent; Place of Payment; Security Registrar and Transfer Agent.		10
	Section 112.	Notices.		11
	Section 113.	Jurisdiction; Venue and Service of Process.		11
ARTICLE II MISCELLANEOUS PROVISIONS				11
	Section 201.	Ratification and Incorporation of Base Indenture.		11
	Section 202.	Executed in Counterparts.		11
	Section 203.	Assignment.		11
	Section 204.	Trustee’s Disclaimer.		11

¹  This Table of Contents does not constitute part of the Indenture or have any bearing upon the interpretation of any of its terms and provisions.

-i-

THIS NINTH SUPPLEMENTAL INDENTURE is made as of the 1st day of June, 2016, by and between DOMINION GAS HOLDINGS, LLC, a Virginia limited liability company, having its principal office at 120 Tredegar Street, Richmond, Virginia 23219 (the “Company” or “Issuer”) and DEUTSCHE BANK TRUST COMPANY AMERICAS, a New York banking corporation, as Trustee, having a corporate trust office at 60 Wall Street, 16th Floor, New York, New York 10005 (the “Trustee”).

W I T N E S S E T H:

WHEREAS, the Company has heretofore entered into an Indenture dated as of October 1, 2013, among the Company and the Trustee (as amended, restated or otherwise modified, the “Base Indenture”) with respect to senior debt securities;

WHEREAS, the Base Indenture is incorporated herein by this reference and the Base Indenture, as heretofore supplemented, as further supplemented by this Ninth Supplemental Indenture, and as may be hereafter supplemented or amended from time to time, is herein called the “Indenture”;

WHEREAS, under the Base Indenture, a new series of Securities may at any time be established in accordance with the provisions of the Base Indenture and the terms of such series may be described by a supplemental indenture executed by the Company and the Trustee;

WHEREAS, the Company proposes to create under the Indenture a new series of Securities;

WHEREAS, additional Securities of other series hereafter established, except as may be limited in the Base Indenture as at the time supplemented, amended and modified, may be issued from time to time pursuant to the Indenture as at the time supplemented, amended and modified; and

WHEREAS, all conditions necessary to authorize the execution and delivery of this Ninth Supplemental Indenture and to make it a valid and binding obligation of the Company have been done or performed.

NOW, THEREFORE, in consideration of the agreements and obligations set forth herein and for other good and valuable consideration, the sufficiency of which is hereby acknowledged, the parties hereto hereby agree as follows:

ARTICLE I

2016 SERIES B 1.45% SENIOR NOTES DUE 2026

Section 101. Establishment. There is hereby established a new series of Securities to be issued under the Indenture, to be designated as the Company’s 2016 Series B 1.45% Senior Notes due 2026 (the “Series B Senior Notes”).

There are to be authenticated and delivered €250,000,000 principal amount of Series B Senior Notes, and such principal amount of the Series B Senior Notes may be increased from time to time pursuant to the penultimate paragraph of Section 301 of the Base Indenture. All

Series B Senior Notes need not be issued at the same time and such series may be reopened at any time, without the consent of any Holder, for issuances of additional Series B Senior Notes. Any such additional Series B Senior Notes will have the same interest rate, maturity and other terms as those initially issued. Further Series B Senior Notes may also be authenticated and delivered as provided by Sections 304, 305, 306, 905 or 1107 of the Base Indenture, and shall be consolidated with and part of the same series of Series B Senior Notes initially issued under this Ninth Supplemental Indenture.

The Series B Senior Notes shall be issued as Registered Securities in global form without coupons, in substantially the form set out in Exhibit A hereto. The entire initially issued principal amount of the Series B Senior Notes shall initially be evidenced by one or more certificates which shall be deposited with, or on behalf of, Clearstream Banking, société anonyme (“Clearstream”) and Euroclear Bank S.A./N.V., as operator of the Euroclear system (“Euroclear”) and registered in the name of the Common Depositary or its nominee for, and in respect of interests held through, Clearstream and Euroclear.

Each Series B Senior Note shall be dated the date of authentication thereof and shall bear interest from the date of original issuance thereof or from the most recent Interest Payment Date to which interest has been paid or duly provided for.

Section 102. Definitions. The following defined terms used herein shall, unless the context otherwise requires, have the meanings specified below. Capitalized terms used herein for which no definition is provided herein shall have the meanings set forth in the Base Indenture. Unless the context otherwise requires, any reference to a “Section” refers to a Section of this Ninth Supplemental Indenture.

“Actual/Actual (ICMA)” has the meaning ascribed to it in Section 103.

“Additional Amounts” has the meaning ascribed to in Section 108.

“Bund Business Day” means each day that is not a Saturday, a Sunday or a day on which commercial banking institutions are not required to be open in the State of New York, Germany, Ireland or at the Place of Payment for the Series B Senior Notes.

“Bund Rate” means, with respect to any Redemption Date, the rate per annum equal to the equivalent yield to maturity as of such Redemption Date of the Comparable German Bund Issue, assuming a price for the Comparable German Bund Issue (expressed as a percentage of its principal amount) equal to the Comparable German Bund Price for such Redemption Date.

“Business Day” means any day except (i) a Saturday or a Sunday, (ii) a day on which banking institutions in the place of payment for the Series B Senior Notes are authorized or required by law, regulation or executive order to close, (iii) a day on which the Trans-European Automated Real-time Gross Settlement Express Transfer system (the TARGET2 system), or any successor thereto, is closed, or (iv) a day on which the Corporate Trust Office of the Trustee is closed.

“Clearstream” has the meaning ascribed to it in Section 101.

2

“Code” has the meaning ascribed to it in Section 108(i)(d).

“Common Depositary” means a depositary common to Clearstream and Euroclear, being initially Deutsche Bank AG, London Branch, until a successor Common Depositary, if any, shall have become such pursuant to this Indenture, and thereafter Common Depositary shall mean or include each Person who is then a Common Depositary hereunder.

“Comparable German Bund Issue” means the German Bundesanleihe security selected by any Reference German Bund Dealer as having a fixed maturity most nearly equal to the period from any Redemption Date to the Stated Maturity, and that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of euro-denominated corporate debt securities in a principal amount approximately equal to the then outstanding principal amount of the Series B Senior Notes and of a maturity most nearly equal to the Stated Maturity; provided, however, that, if the period from such Redemption Date to the Stated Maturity is less than one (1) year, a fixed maturity of one (1) year shall be used.

“Comparable German Bund Price” means, for any Redemption Date, (i) the average of the Reference German Bund Dealer Quotations for such date (which, in any event, must include at least two (2) such quotations), after excluding the highest and lowest Reference German Bund Dealer Quotations, or (ii) if the Company obtains fewer than four (4) such Reference German Bund Dealer Quotations, the average of all such quotations.

“euro” has the meaning ascribed to it in Section 103.

“Euroclear” has the meaning ascribed to it in Section 101.

“Interest Payment Date” means June 30 of each year, commencing on June 30, 2017, and the final Interest Payment Date shall be June 30, 2026.

“Original Issue Date” means June 22, 2016.

“Outstanding,” when used with respect to the Series B Senior Notes, means, as of the date of determination, all Series B Senior Notes theretofore authenticated and delivered under the Indenture, except:

(i) Series B Senior Notes theretofore canceled by the Trustee or delivered to the Trustee for cancellation;

(ii) Series B Senior Notes for whose payment at the Maturity thereof money in the necessary amount has been theretofore deposited (other than pursuant to Section 402 of the Base Indenture) with the Trustee or any Paying Agent (other than the Company) in trust or set aside and segregated in trust by the Company (if the Company shall act as its own Paying Agent) for the Holders of such Series B Senior Notes, provided that, if such Series B Senior Notes are to be redeemed, notice of such redemption has been duly given pursuant to the Indenture or provision therefor satisfactory to the Trustee has been made;

3

(iii) Series B Senior Notes with respect to which the Company has effected defeasance or covenant defeasance pursuant to Section 402 of the Base Indenture, except to the extent provided in Section 402 of the Base Indenture; and

(iv) Series B Senior Notes that have been paid pursuant to Section 306 of the Base Indenture or in exchange for or in lieu of which other Series B Senior Notes have been authenticated and delivered pursuant to the Indenture, other than any such Series B Senior Notes in respect of which there shall have been presented to the Trustee proof satisfactory to it that such Series B Senior Notes are held by a bona fide purchaser in whose hands such Series B Senior Notes are valid obligations of the Company;

provided, however, that in determining whether the Holders of the requisite principal amount of Outstanding Series B Senior Notes have given any request, demand, authorization, direction, notice, consent or waiver under the Indenture or are present at a meeting of Holders of Series B Senior Notes for quorum purposes, the principal amount of the Series B Senior Notes shall be the Dollar equivalent, determined on the Original Issue Date, of the principal amount of such Series B Senior Notes, and any Series B Senior Notes owned by the Company or any other obligor upon the Series B Senior Notes or any Affiliate of the Company or such other obligor shall be disregarded and deemed not to be Outstanding, except that, in determining whether the Trustee shall be protected in making any such determination or relying upon any such request, demand, authorization, direction, notice, consent or waiver, only those Series B Senior Notes which a Responsible Officer of the Trustee actually knows to be so owned shall be so disregarded. Series B Senior Notes so owned which shall have been pledged in good faith may be regarded as Outstanding if the pledgee establishes to the satisfaction of the Trustee (a) the pledgee’s right so to act with respect to such Series B Senior Notes and (b) that the pledgee is not the Company or any other obligor upon the Series B Senior Notes or an Affiliate of the Company or such other obligor.

“Reference German Bund Dealer” means any dealer of German Bundesanleihe securities appointed by the Company in good faith.

“Reference German Bund Dealer Quotations” means, with respect to each Reference German Bund Dealer and any Redemption Date, the average as determined by the Company of the bid and offered prices for the Comparable German Bund Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Company by such Reference German Bund Dealer at 3:30 p.m., Frankfurt, Germany time, on the third Bund Business Day preceding such Redemption Date.

“Regular Record Date” means, with respect to each Interest Payment Date, the close of business on the Business Day preceding such Interest Payment Date; provided, that with respect to Series B Senior Notes that are not represented by one or more Global Securities, the Regular Record Date shall be the close of business on the fifteenth (15th) calendar day (whether or not a Business Day) preceding such Interest Payment Date.

“Remaining Scheduled Payments” means the remaining scheduled payments of the principal of and interest on the Series B Senior Notes (excluding accrued but unpaid interest) to the Stated Maturity that would be due after the related Redemption Date but for such

4

redemption; provided, however, that, if any Redemption Date is not an Interest Payment Date with respect to the Series B Senior Notes, the amount of the next scheduled interest payment thereon will be reduced by the amount of interest accrued thereon to such Redemption Date.

“Securities Act” means the Securities Act of 1933, as amended.

“Series B Senior Notes” has the meaning ascribed to it in Section 101.

“Stated Maturity” means June 30, 2026.

“Tax Event” means the receipt by the Company of an opinion of independent counsel selected by the Company to the effect that, as a result of any change in, or amendment to, applicable laws (or any regulations or rulings promulgated under applicable laws), or any change in, or amendment to, an official position regarding the application or interpretation of such laws, regulations or rulings (including a holding by a court of competent jurisdiction), which change or amendment is formally announced or becomes effective on or after June 20, 2016, the Company becomes or will become obligated to pay Additional Amounts as described in Section 108 with respect to the Series B Senior Notes.

“Taxes” has the meaning ascribed to it in Section 108.

“U.S.” has the meaning ascribed to it in Section 108.

“U.S. person” has the meaning ascribed to it in Section 108.

The terms “Company,” “Issuer,” “Trustee,” “Base Indenture,” and “Indenture” shall have the respective meanings set forth in the recitals to this Ninth Supplemental Indenture and the paragraph preceding such recitals.

Section 103. Payment of Principal and Interest. The principal of the Series B Senior Notes shall be due at the Stated Maturity (unless earlier redeemed). The unpaid principal amount of the Series B Senior Notes shall bear interest at the rate of 1.45% per annum until paid or duly provided for, such interest to accrue from the Original Issue Date or from the most recent Interest Payment Date to which interest has been paid or duly provided for. Interest shall be paid annually in arrears on each Interest Payment Date to the Person in whose name the Series B Senior Notes are registered on the Regular Record Date for such Interest Payment Date; provided that interest payable at the Stated Maturity of principal or on a Redemption Date as provided herein will be paid to the Person to whom principal is payable. Any such interest that is not so punctually paid or duly provided for will forthwith cease to be payable to the Holders on such Regular Record Date and may either be paid to the Person or Persons in whose name the Series B Senior Notes are registered at the close of business on a Special Record Date for the payment of such defaulted interest to be fixed by the Trustee (in accordance with Section 307 of the Base Indenture), notice whereof shall be given to Holders of the Series B Senior Notes not less than ten (10) days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange, if any, on which the Series B Senior Notes may be listed, and upon such notice as may be required by any such exchange, all as more fully provided in the Base Indenture.

5

Payments of interest on the Series B Senior Notes will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the Series B Senior Notes shall be computed and paid on the basis of the actual number of days from and including the last Interest Payment Date (or June 22, 2016 if no interest has been paid on the Series B Senior Notes), to but excluding the next scheduled Interest Payment Date. This payment convention is referred to as “Actual/Actual (ICMA)”, as defined in the rulebook of the International Capital Market Association. In the event that any Interest Payment Date is not a Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Payment of the principal and interest on the Series B Senior Notes shall be made at the office of an Affiliate of the Trustee in London, United Kingdom, as designated in writing from time to time by the Trustee, in the single currency of participating member states of the economic and monetary union as contemplated in the Treaty on European Union (the “euro” or “€”),with any such payment that is due at the Stated Maturity of any Series B Senior Notes, upon redemption or repurchase being made upon surrender of such Series B Senior Notes to the Paying Agent; provided that payments of interest (including interest on any Interest Payment Date) will be made, subject to such surrender where applicable, at the option of the Company, (i) by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (ii) by wire transfer at such place and to such account at a banking institution as may be designated in writing to the Company and the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto. In the event that any date on which principal and interest is payable on the Series B Senior Notes is not a Business Day, then payment of the principal and interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Section 104. Denominations. The Series B Senior Notes may be issued in denominations of €100,000, or any greater integral multiple of €1,000.

Section 105 .Global Securities. The Series B Senior Notes will be initially issued in the form of one or more Global Securities registered in the name of the Common Depositary or its nominee. Except under the limited circumstances described below, Series B Senior Notes represented by such Global Securities will not be exchangeable for, and will not otherwise be issuable as, Series B Senior Notes in definitive form registered in names other than the Common Depositary or its nominee. The Global Securities described above may not be transferred except by the Common Depositary to a nominee of the Common Depositary or by a nominee of the Common Depositary to the Common Depositary or another nominee of the Common Depositary or to a successor Common Depositary or its nominee.

Owners of beneficial interests in such a Global Security will not be considered the Holders thereof for any purpose under the Indenture, and no Global Security representing a Series B Senior Note shall be exchangeable, except for another Global Security of like denomination and tenor to be registered in the name of the Common Depositary or its nominee or to a successor Common Depositary or its nominee or except as described below. The rights of Holders of such Global Security shall be exercised only through the Common Depositary.

6

A Global Security shall be exchangeable for Series B Senior Notes registered in the names of persons other than the Common Depositary or its nominee only if (i) Clearstream, Euroclear or any successor thereto notifies the Company that it is no longer willing or able to act as a clearing system for the Global Securities, or (ii) the Company determines, in its sole discretion, not to have the Series B Senior Notes represented by a Global Security. Certificated Notes issued in exchange for Global Securities, any beneficial interest therein or any portion thereof shall be registered in the names, and issued in any approved denominations, requested by or on behalf of the Common Depositary (in accordance with its customary procedures).

Section 106. Optional Redemption. The Series B Senior Notes are redeemable, in whole or in part, at any time and from time to time at the option of the Company, upon not less than thirty (30) nor more than sixty (60) days’ notice, at a Redemption Price equal to the greater of:

(i) 100% of the aggregate principal amount of Series B Senior Notes then Outstanding to be so redeemed, or

(ii) the sum of the present values of the Remaining Scheduled Payments on the Series B Senior Notes then Outstanding to be so redeemed, discounted to the Redemption Date on an annual basis (using Actual/Actual (ICMA)) at the Bund Rate plus 25 basis points, as calculated by the Company,

plus, in either of the above cases, accrued and unpaid interest thereon to, but excluding, the Redemption Date; provided, however, that Holders of such Series B Senior Notes to be redeemed on the relevant record date shall be entitled to receive interest due on an Interest Payment Date that is on or prior to such Redemption Date.

The Bund Rate shall be calculated on the third (3rd) Bund Business Day preceding the Redemption Date.

Unless the Company defaults in the payment of the Redemption Price, on and after the Redemption Date, interest will cease to accrue on the Series B Senior Notes or portions thereof called for redemption.

In the event of the redemption of the Series B Senior Notes in part only, a new Series B Senior Note or Notes for the unredeemed portion will be issued in the name or names of the Holders thereof upon surrender thereof.

In the case of a partial redemption, no such partial redemption shall reduce the portion of the principal amount of a Series B Senior Note not redeemed to less than €100,000.

If the Company effects an optional redemption of the Series B Senior Notes and at the time of such redemption the Series B Senior Notes (i) are listed on the Official List of the Irish Stock Exchange and are admitted for trading on the Main Securities Market, and (ii) the rules of the Irish Stock Exchange so require, the Company will inform the Irish Stock Exchange of such

7

optional redemption by filing a notice of redemption in the Companies’ Announcement Office of the Irish Stock Exchange, including a confirmation of the aggregate principal amount of the Series B Senior Notes that remain after such redemption (if such optional redemption is for a part of the Series B Senior Notes).

The Company shall notify the Trustee of the Redemption Price in writing promptly after the calculation thereof and the Trustee shall have no responsibility for such calculation. Notices of redemption shall be mailed by first-class mail to each Holder of Series B Senior Notes to be redeemed at its registered address, or delivered electronically to the e-mail address, if any, provided to the Security Registrar by the Holder for such purpose.

Section 107. Tax Redemption. The Company shall have the option to redeem the Series B Senior Notes at any time, in whole but not in part, at a Redemption Price equal to 100% of the aggregate principal amount of the Series B Senior Notes then Outstanding, plus accrued and unpaid interest thereon to, but excluding, the Redemption Date, upon the occurrence of a Tax Event; provided the Company delivers notice to the Trustee no later than ten (10) Business Days prior to the date fixed for redemption specifying the date fixed for such redemption.

Section 108. Additional Amounts. All payments of principal and interest on the Series B Senior Notes by the Company will be made free and clear of and without withholding or deduction for or on account of any present or future tax, assessment or other governmental charge imposed by the United States or any political subdivision or taxing authority thereof or therein having power to tax (collectively, “Taxes”), unless the withholding or deduction of such Taxes is required by law.

If any deduction or withholding for, or on account of, any Taxes will at any time be required to be made from any payments made by the Company under or with respect to the Series B Senior Notes to a Holder who is not a U.S. person (as defined below), then the Company will pay to such Holder of Series B Senior Notes such additional amounts (“Additional Amounts”) as may be necessary so that the net amount received by such Holder (including the Additional Amounts) after such withholding or deduction will not be less than the amount such Holder would have received if such Taxes had not been withheld or deducted; provided, that the foregoing obligation shall not apply:

(i) to the extent any Taxes are imposed by reason of the Holder (or the beneficial owner for whose benefit such Holder holds such Series B Senior Note, or a fiduciary, settlor, beneficiary, member or shareholder of the Holder if the Holder is an estate, trust, partnership or corporation, or a person holding a power over an estate or trust administered by a fiduciary Holder) being considered as:

(a) being or having been engaged in a trade or business in the United States or having or having had a permanent establishment in the United States;

(b) having a current or former connection with the United States (other than a connection arising solely as a result of the ownership of the Series B Senior Notes, the receipt of any payment or the enforcement of any rights hereunder), including being or having been a citizen or resident of the United States;

8

(c) being or having been a personal holding company, a passive foreign investment company or a controlled foreign corporation for U.S. income tax purposes or a corporation that has accumulated earnings to avoid U.S. federal income tax;

(d) being or having been a “10-percent shareholder” of the Company as defined in section 871(h)(3) of the U.S. Internal Revenue Code of 1986, as amended (the “Code”) or any successor provision; or

(e) being a bank receiving payments on an extension of credit made pursuant to a loan agreement entered into in the ordinary course of its trade or business, as described in section 881(c)(3)(A) of the Code or any successor provision;

(ii) to any Holder that is not the sole beneficial owner of the Series B Senior Notes, or a portion of the Series B Senior Notes, or that is a fiduciary, partnership or limited liability company, but only to the extent that a beneficial owner with respect to the Holder, a beneficiary or settlor with respect to the fiduciary, or a beneficial owner or member of the partnership or limited liability company would not have been entitled to the payment of an Additional Amount had the beneficiary, settlor, beneficial owner or member received directly its beneficial or distributive share of the payment;

(iii) to the extent any Taxes that would not have been imposed but for the failure of the Holder or any other person to timely comply with certification, identification or information reporting requirements concerning the nationality, residence, identity or connection with the United States of the Holder or beneficial owner of the Series B Senior Notes, if compliance is required by statute, by regulation of the United States or any taxing authority therein or by an applicable income tax treaty to which the United States is a party as a precondition to exemption from such Taxes;

(iv) to any Taxes that are imposed other than by withholding by the Company or a Paying Agent;

(v) to any estate, inheritance, gift, sales, transfer, wealth, capital gains or personal property Taxes or similar Taxes, or to any Taxes imposed on the transfer of Series B Senior Notes;

(vi) to any Taxes imposed under sections 1471 through 1474 of the Code (or any amended or successor provisions), any current or future regulations or official interpretations thereof, any agreement entered into pursuant to section 1471(b) of the Code or any fiscal or regulatory legislation, rules or practices adopted pursuant to any intergovernmental agreement entered into in connection with the implementation of such sections of the Code;

(vii) to any Taxes required to be withheld by any Paying Agent, if such payment can be made without such withholding by at least one other Paying Agent;

9

(viii) to the extent any Taxes would not have been imposed but for the presentation by the Holder of any Series B Senior Note, where presentation is required, for payment on a date more than thirty (30) days after the date on which payment became due and payable or the date on which payment thereof is duly provided for, whichever occurs later; or

(ix) in the case of any combination of the foregoing.

Except as specifically provided under this Section 108, the Company will not be required to make any payment for any Taxes imposed by any government or a political subdivision or taxing authority of or in any government or political subdivision.

As used in this Section 108, the term “U.S.” means the United States of America, the states of the United States and the District of Columbia, and the term “U.S. person” means any individual who is a citizen or resident of the United States for U.S. federal income tax purposes, a corporation, partnership or other entity created or organized in or under the laws of the United States, any state of the United States or the District of Columbia, or any estate or trust the income of which is subject to U.S. federal income taxation regardless of its source.

Section 109. Sinking Fund; Conversion. The Series B Senior Notes shall not have a sinking fund. The Series B Senior Notes are not convertible into or exchangeable for Equity Securities or any other securities.

Section 110. Additional Interest on Overdue Amounts. Any principal of and installment of interest on the Series B Senior Notes that is overdue shall bear interest at the rate of 1.45% per annum (to the extent that the payment of such interest shall be legally enforceable), from the dates such amounts are due until they are paid or made available for payment, and such interest shall be payable on demand.

Section 111. Paying Agent; Place of Payment; Security Registrar and Transfer Agent. The Trustee shall initially serve as Paying Agent with respect to the Series B Senior Notes, but the Company or any of its subsidiaries may act as Paying Agent in respect of the Series B Senior Notes. The Place of Payment for the Series B Senior Notes issued hereunder shall be the office of an Affiliate of the Trustee in London, United Kingdom, as designated in writing from time to time by the Trustee. In addition, the Company undertakes that, to the extent reasonably practicable and permitted by law, the Company will, for as long as Series B Senior Notes issued hereunder remain Outstanding, use its commercially reasonable efforts to maintain a Place of Payment in a Member State of the European Union (if any) that will not be obliged to withhold or deduct tax pursuant to U.S. law in the event definitive registered Series B Senior Notes are issued.

The Company may change the Paying Agent, Place of Payment, the Security Registrar or the Transfer Agent without prior notice to the Holders of the Series B Senior Notes. For so long as the Series B Senior Notes are listed on the Official List of the Irish Stock Exchange and admitted for trading on the Main Securities Market, however, the Company will file a notice of any change of Paying Agent, Place of Payment, Security Registrar or Transfer Agent in the Companies Announcement Office of the Irish Stock Exchange.

10

Section 112. Notices. So long as any Series B Senior Notes are listed on the Irish Stock Exchange and to the extent required by the Irish Stock Exchange, in addition to providing notice to Holders as set forth in Section 106 of the Base Indenture, the Company will also file notices with the Companies Announcements Office of the Irish Stock Exchange.

Section 113. Jurisdiction; Venue and Service of Process. The Company hereby submits to the nonexclusive jurisdiction of the Supreme Court of the State of New York sitting in New York County and of the United States District Court of the Southern District of New York, and any appellate court from any such court, in any action or proceeding arising out of or relating to this Ninth Supplemental Indenture, and hereby irrevocably waives, to the fullest extent it may legally and effectively do so, any objection which it may now or hereafter have to the laying of venue of any such proceeding brought in such a court and any claim that any such proceeding brought in such a court has been brought in an inconvenient forum. The Company irrevocably consents to the service of process out of any competent court in any action or proceeding brought in connection with this Ninth Supplemental Indenture by the mailing of copies thereof by registered or certified mail, postage prepaid, to it at its address noted in the recitals of this Ninth Supplemental Indenture, such service to become effective thirty (30) days after such mailing.

ARTICLE II

MISCELLANEOUS PROVISIONS

Section 201. Ratification and Incorporation of Base Indenture. As supplemented hereby, the Base Indenture is in all respects ratified and confirmed by the Company, and the Base Indenture and this Ninth Supplemental Indenture shall be read, taken and construed as one and the same instrument.

Section 202. Executed in Counterparts. This Ninth Supplemental Indenture may be executed in several counterparts, each of which shall be deemed to be an original, and such counterparts shall together constitute but one and the same instrument. The exchange of copies of this Ninth Supplemental Indenture and of signature pages by facsimile or PDF transmission shall constitute effective execution and delivery of this Ninth Supplemental Indenture as to the parties hereto and may be used in lieu of the original manually executed Ninth Supplemental Indenture for all purposes. Signatures of the parties hereto transmitted by facsimile or PDF shall be deemed to be their original signatures for all purposes.

Section 203. Assignment. The Company shall have the right at all times to assign any of its rights or obligations under the Indenture with respect to the Series B Senior Notes to a direct or indirect wholly owned subsidiary of the Company; provided that, in the event of any such assignment, the Company shall remain primarily liable for the performance of all such obligations. The Indenture may also be assigned by the Company in connection with a transaction described in Article VIII of the Base Indenture.

Section 204. Trustee’s Disclaimer. All of the provisions contained in the Base Indenture in respect of the rights, powers, privileges, protections, duties and immunities of the Trustee, including without limitation its right to be indemnified, shall be applicable in respect of

11

the Series B Senior Notes and of this Ninth Supplemental Indenture as fully and with like effect as if set forth herein in full. The Trustee accepts the amendments of the Indenture effected by this Ninth Supplemental Indenture, but on the terms and conditions set forth in the Indenture, including the terms and provisions defining and limiting the liabilities and responsibilities of the Trustee. Without limiting the generality of the foregoing, the Trustee shall not be responsible in any manner whatsoever for or with respect to any of the recitals or statements contained herein, all of which recitals or statements are made solely by the Company, or for or with respect to (i) the validity or sufficiency of this Ninth Supplemental Indenture or any of the terms or provision hereof, (ii) the proper authorization hereof by the Company by action or otherwise, (iii) the due execution hereof by the Company, or (iv) the consequences of any amendment herein provided for, and the Trustee makes no representation with respect to any such matters.

[Signature Page Follows]

12

IN WITNESS WHEREOF, each party hereto has caused this instrument to be signed in its name and behalf by its duly authorized officer, all as of the day and year first above written.

DOMINION GAS HOLDINGS, LLC
By:	/s/ James R. Chapman
Name:	James R. Chapman
Title:	Senior Vice President – Mergers &
	Acquisitions and Treasurer
DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:	/s/ Carol Ng
Name:	Carol Ng
Title:	Vice President
By:	/s/ Randy Kahn
Name:	Randy Kahn
Title:	Vice President

13

EXHIBIT A

FORM OF

2016 SERIES B 1.45% SENIOR NOTE

DUE 2026

[UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF DEUTSCHE BANK AG, LONDON BRANCH AS COMMON DEPOSITARY FOR CLEARSTREAM BANKING, SOCIÉTÉ ANONYME, LUXEMBOURG, AND EUROCLEAR BANK S.A./N.V., AS OPERATOR OF THE EUROCLEAR SYSTEM (THE “COMMON DEPOSITARY”), TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF BT GLOBENET NOMINEES LIMITED OR SUCH OTHER NAME AS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE COMMON DEPOSITARY AND ANY PAYMENT IS MADE TO BT GLOBENET NOMINEES LIMITED OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE COMMON DEPOSITARY, ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL SINCE THE REGISTERED OWNER HEREOF, BT GLOBENET NOMINEES LIMITED, HAS AN INTEREST HEREIN.]**

[THIS SERIES B SENIOR NOTE IS A GLOBAL SECURITY WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF BT GLOBENET NOMINEES LIMITED. THIS SERIES B SENIOR NOTE MAY NOT BE EXCHANGED IN WHOLE OR IN PART FOR A SECURITY REGISTERED, AND NO TRANSFER OF THIS SERIES B SENIOR NOTE IN WHOLE OR IN PART MAY BE REGISTERED, IN THE NAME OF ANY PERSON OTHER THAN SUCH COMMON DEPOSITARY OR A NOMINEE THEREOF, EXCEPT IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE. EVERY SERIES B SENIOR NOTE AUTHENTICATED AND DELIVERED UPON REGISTRATION OF, TRANSFER OF, OR IN EXCHANGE FOR OR IN LIEU OF, THIS SERIES B SENIOR NOTE SHALL BE A GLOBAL SECURITY SUBJECT TO THE FOREGOING, EXCEPT IN SUCH LIMITED CIRCUMSTANCES.]**

THIS SECURITY HAS NOT BEEN REGISTERED UNDER THE U.S. SECURITIES ACT OF 1933, AS AMENDED (THE “U.S. SECURITIES ACT”), OR THE SECURITIES LAWS OF ANY STATE OR OTHER JURISDICTION. NEITHER THIS SECURITY NOR ANY INTEREST OR PARTICIPATION HEREIN MAY BE REOFFERED, SOLD, ASSIGNED, TRANSFERRED, PLEDGED, ENCUMBERED OR OTHERWISE DISPOSED OF IN THE ABSENCE OF SUCH REGISTRATION OR UNLESS SUCH TRANSACTION IS EXEMPT FROM, OR NOT SUBJECT TO, THE REGISTRATION REQUIREMENTS OF THE U.S. SECURITIES ACT.

THE HOLDER OF THIS SECURITY, BY ITS ACCEPTANCE HEREOF, AGREES ON ITS OWN BEHALF AND ON BEHALF OF ANY INVESTOR FOR WHICH IT HAS

** Insert in Global Securities.

A-1

PURCHASED SECURITIES TO OFFER, SELL OR OTHERWISE TRANSFER SUCH SECURITY, PRIOR TO THE DATE WHICH IS 40 DAYS AFTER THE LATER OF THE ORIGINAL ISSUE DATE HEREOF AND THE DATE ON WHICH THE SECURITY (OR ANY PREDECESSOR OF THIS SECURITY) WAS FIRST OFFERED TO PERSONS OTHER THAN DISTRIBUTORS (AS DEFINED IN RULE 902 OF REGULATION S) IN RELIANCE ON REGULATION S, ONLY (A) TO THE ISSUER, (B) PURSUANT TO A REGISTRATION STATEMENT WHICH HAS BEEN DECLARED EFFECTIVE UNDER THE U.S. SECURITIES ACT, (C) PURSUANT TO OFFERS AND SALES THAT OCCUR OUTSIDE THE UNITED STATES IN COMPLIANCE WITH THE U.S. SECURITIES ACT, OR (D) PURSUANT TO ANY OTHER AVAILABLE EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE U.S. SECURITIES ACT, SUBJECT IN EACH OF THE FOREGOING CASES TO ANY REQUIREMENT OF LAW THAT THE DISPOSITION OF ITS PROPERTY OR THE PROPERTY OF SUCH INVESTOR ACCOUNT OR ACCOUNTS BE AT ALL TIMES WITHIN ITS OR THEIR CONTROL AND IN COMPLIANCE WITH ANY APPLICABLE STATE SECURITIES LAWS; AND ANY APPLICABLE LOCAL LAWS AND REGULATIONS.

THE HOLDER OF THIS NOTE, BY ITS ACCEPTANCE HEREOF, AGREES ON ITS OWN BEHALF AND ON BEHALF OF ANY INVESTOR ACCOUNT FOR WHICH IT HAS PURCHASED SECURITIES THAT IT SHALL NOT TRANSFER THE SECURITIES IN AN AMOUNT LESS THAN €100,000.

A-2

DOMINION GAS HOLDINGS, LLC

€[                ]

2016 SERIES B 1.45% SENIOR NOTE

DUE 2026

No. R-	ISIN No. XS1435300519
	Euroclear and Clearstream Common Code No. 143530051

Dominion Gas Holdings, LLC, a limited liability company duly organized and existing under the laws of Virginia (herein called the “Company” or the “Issuer,” which terms include any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to BT Globenet Nominees Limited**, or registered assigns (the “Holder”), the principal sum of [            ] euros (€[            ]) on June 30, 2026 and to pay interest thereon from June 22, 2016 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, annually in arrears on June 30 of each year, commencing on June 30, 2017, with the final Interest Payment Date being June 30, 2026, at the rate of 1.45% per annum, until the principal hereof is paid or made available for payment, provided that any principal, and any such installment of interest, that is overdue shall bear interest at the rate of 1.45% per annum (to the extent that the payment of such interest shall be legally enforceable), from the dates such amounts are due until they are paid or made available for payment, and such interest shall be payable on demand. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in such Indenture, be paid to the Person in whose name this Series B Senior Note (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date for such interest; provided that the interest payable at Stated Maturity or on a Redemption Date will be paid to the Person to whom principal is payable. The Regular Record Date shall be the close of business on the Business Day preceding such Interest Payment Date; provided, that with respect to Series B Senior Notes that are not represented by one or more Global Securities, the Regular Record Date shall be the close of business on the fifteenth (15th) calendar day (whether or not a Business Day) preceding such Interest Payment Date. Any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Series B Senior Note (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Series B Senior Notes not less than ten (10) days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Series B Senior Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.

Payments of interest on the Series B Senior Notes will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the Series B Senior Notes shall be computed and paid on the basis of the actual number of days from and including the last Interest Payment Date (or June 22, 2016 if no interest has been paid on the Series B Senior Notes), to but excluding the next scheduled Interest Payment Date. This payment convention is referred to as “Actual/Actual (ICMA)”, as defined in the rulebook of the International Capital

A-3

Market Association. In the event that any date on which interest is payable on the Series B Senior Notes is not a Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Payment of the principal of and interest on this Series B Senior Note will be made at the office of an Affiliate of the Trustee in London, United Kingdom, as designated in writing from time to time by the Trustee, in the single currency of participating member states of the economic and monetary union as contemplated in the Treaty on European Union (the “euro” or “€”), with any such payment that is due at the Stated Maturity of any Series B Senior Note, upon redemption or repurchase being made upon surrender of such Series B Senior Note to such office or agency; provided, however, that at the option of the Company payment of interest, subject to such surrender where applicable, may be made (i) by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (ii) by wire transfer at such place and to such account at a banking institution as may be designated in writing to the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto. In the event that any date on which principal and interest is payable on the Series B Senior Notes is not a Business Day, then payment of the principal and interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Reference is hereby made to the further provisions of this Series B Senior Note set forth on the reverse hereof, which further provisions shall for all purposes have the same effect as if set forth at this place.

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse hereof by manual signature, this Series B Senior Note shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

A-4

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

Dated:	DOMINION GAS HOLDINGS, LLC
	By:
	Name:
	Title:

TRUSTEE’S CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:
	Authorized Signatory
Dated:

A-5

[REVERSE OF 2016 SERIES B 1.45% SENIOR NOTE]

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture dated as of October 1, 2013 (the “Base Indenture”), among the Company and Deutsche Bank Trust Company Americas, as Trustee (the “Trustee”), as heretofore supplemented and as further supplemented by a Ninth Supplemental Indenture dated as of June 1, 2016 (the “Ninth Supplemental Indenture” and together with the Base Indenture, as it may be hereafter supplemented or amended from time to time, the “Indenture,” which term shall have the meaning assigned to it in such instrument), by and between the Company and the Trustee, and reference is hereby made to the Indenture for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities and of the terms upon which the Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof (the “Series B Senior Notes”) which is unlimited in aggregate principal amount.

The Series B Senior Notes are redeemable, in whole or in part, at any time and from time to time in the manner and with the effect provided in the Indenture.

If an Event of Default with respect to Series B Senior Notes shall occur and be continuing, the principal of the Series B Senior Notes may be declared due and payable in the manner and with the effect provided in the Indenture.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected under the Indenture at any time by the Company and the Trustee for the series of Securities affected, with the consent of the Holders of a majority in principal amount of the Securities at the time Outstanding of each series to be affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Series B Senior Note shall be conclusive and binding upon such Holder and upon all future Holders of this Series B Senior Note and of any Series B Senior Note issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Series B Senior Note.

As provided in and subject to the provisions of the Indenture, the Holder of this Series B Senior Note shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Series B Senior Notes, the Holders of not less than a majority in principal amount of the Series B Senior Notes at the time Outstanding shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee indemnity or security reasonably satisfactory to it, and the Trustee shall not have received from the Holders of a majority in principal amount of Series B Senior Notes at the time Outstanding a direction inconsistent with such request, and shall have failed to institute any such

A-6

proceeding for 60 days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Series B Senior Note for the enforcement of any payment of principal hereof or premium, if any, or interest hereon on or after the respective due dates expressed or provided for herein.

No reference herein to the Indenture and no provision of this Series B Senior Note or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of, premium, if any, and interest on this Series B Senior Note at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Series B Senior Note is registrable in the Security Register, upon surrender of this Series B Senior Note for registration of transfer at the office or agency of the Company in any place where the principal of, premium, if any, and interest on this Series B Senior Note are payable, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Series B Senior Notes of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

The Series B Senior Notes are issuable only in registered form without coupons in denominations of €100,000 or any greater integral multiple of €1,000. As provided in the Indenture and subject to certain limitations therein set forth, Series B Senior Notes are exchangeable for a like aggregate principal amount of Series B Senior Notes having the same Stated Maturity and of like tenor of any authorized denominations as requested by the Holder upon surrender of the Series B Senior Note or Series B Senior Notes to be exchanged at the office or agency of the Company.

No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Series B Senior Note for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Series B Senior Note be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

All terms used in this Series B Senior Note that are defined in the Indenture shall have the meanings assigned to them in the Indenture.

A-7

ABBREVIATIONS

The following abbreviations, when used in the inscription on the face of this instrument, shall be construed as though they were written out in full according to applicable laws or regulations:

TEN COM -	as tenants in common
TEN ENT -	as tenants by the entireties
JT TEN -	as joint tenants with rights of survivorship and not as tenants in common
UNIF GIFT MIN ACT -	Custodian for
	(Cust)
	(Minor)
	Under Uniform Gifts to Minors Act of
	(State)

Additional abbreviations may also be used though not on the above list.

A-8

FOR VALUE RECEIVED, the undersigned hereby sell(s) and transfer(s) unto

.

(please insert Social Security or other identifying number of assignee).

.

.

.

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE OF ASSIGNEE

the within Series B Senior Note and all rights thereunder, hereby irrevocably constituting and appointing

.

.

.

.

.

.

agent to transfer said Series B Senior Note on the books of the Company, with full power of substitution in the premises.

Dated:                                        ,                 

NOTICE: The signature to this assignment must correspond with the name as written upon the face of the within instrument in every particular without alteration or enlargement, or any change whatever.

A-9

EX-4.1.C

Exhibit 4.1.c

DOMINION GAS HOLDINGS, LLC,

as Issuer,

and

DEUTSCHE BANK TRUST COMPANY AMERICAS,

as Trustee.

Tenth Supplemental Indenture

Dated as of June 1, 2016

$250,000,000

2016 Series C 2.875% Senior Notes

due 2023

TABLE OF CONTENTS¹

ARTICLE I           2016 SERIES C 2.875% SENIOR NOTES DUE 2023			1
	SECTION 101	Establishment	1
	SECTION 102	Definitions	2
	SECTION 103	Payment of Principal and Interest	4
	SECTION 104	Denominations	5
	SECTION 105	Global Securities	5
	SECTION 106	Redemption	6
	SECTION 107	Sinking Fund; Conversion	7
	SECTION 108	Additional Interest on Overdue Amounts	7
	SECTION 109	Paying Agent; Security Registrar	7
ARTICLE II         TRANSFER AND EXCHANGE			7
	SECTION 201	Transfer and Exchange of Global Securities	7
	SECTION 202	Restricted Legend	7
	SECTION 203	Removal of Restricted Legend	9
	SECTION 204	Registration of Transfer or Exchange	9
	SECTION 205	Preservation of Information	10
	SECTION 206	Acknowledgment of Restrictions; Indemnification; No Obligation of Trustee	10
ARTICLE III       MISCELLANEOUS PROVISIONS			11
	SECTION 301	Ratification and Incorporation of Base Indenture	11
	SECTION 302	Executed in Counterparts	11
	SECTION 303	Assignment	11
	SECTION 304	Trustee’s Disclaimer	11

¹  This Table of Contents does not constitute part of the Indenture or have any bearing upon the interpretation of any of its terms and provisions.

THIS TENTH SUPPLEMENTAL INDENTURE is made as of the 1st day of June, 2016, by and between DOMINION GAS HOLDINGS, LLC, a Virginia limited liability company, having its principal office at 120 Tredegar Street, Richmond, Virginia 23219 (the “Company” or “Issuer”), and DEUTSCHE BANK TRUST COMPANY AMERICAS, a New York banking corporation, as Trustee, having a corporate trust office at 60 Wall Street, 16^th Floor, New York, New York 10005 (the “Trustee”).

W I T N E S S E T H:

WHEREAS, the Company has heretofore entered into an Indenture dated as of October 1, 2013, among the Company and the Trustee (as amended, restated or otherwise modified, the “Base Indenture”) with respect to senior debt securities;

WHEREAS, the Base Indenture is incorporated herein by this reference and the Base Indenture, as heretofore supplemented, as further supplemented by this Tenth Supplemental Indenture, and as may be hereafter supplemented or amended from time to time, is herein called the “Indenture”;

WHEREAS, under the Base Indenture, a new series of Securities may at any time be established in accordance with the provisions of the Base Indenture and the terms of such series may be described by a supplemental indenture executed by the Company and the Trustee;

WHEREAS, the Company proposes to create under the Indenture a new series of Securities;

WHEREAS, additional Securities of other series hereafter established, except as may be limited in the Base Indenture as at the time supplemented, amended and modified, may be issued from time to time pursuant to the Indenture as at the time supplemented, amended and modified; and

WHEREAS, all conditions necessary to authorize the execution and delivery of this Tenth Supplemental Indenture and to make it a valid and binding obligation of the Company have been done or performed.

NOW, THEREFORE, in consideration of the agreements and obligations set forth herein and for other good and valuable consideration, the sufficiency of which is hereby acknowledged, the parties hereto hereby agree as follows:

ARTICLE I

2016 SERIES C 2.875% SENIOR NOTES DUE 2023

SECTION 101 Establishment. There is hereby established a new series of Securities to be issued under the Indenture, to be designated as the Company’s 2016 Series C 2.875% Senior Notes due 2023 (the “Series C Senior Notes”).

There are to be authenticated and delivered $250,000,000 principal amount of Series C Senior Notes, and such principal amount of the Series C Senior Notes may be increased from time to time pursuant to the penultimate paragraph of Section 301 of the Base Indenture. All

Series C Senior Notes need not be issued at the same time and such series may be reopened at any time, without the consent of any Holder, for issuances of additional Series C Senior Notes. Any such additional Series C Senior Notes will have the same interest rate, maturity and other terms as those initially issued. Further Series C Senior Notes may also be authenticated and delivered as provided by Sections 304, 305, 306, 905 or 1107 of the Base Indenture, and shall be consolidated with and part of the same series of Series C Senior Notes initially issued under this Tenth Supplemental Indenture.

The Series C Senior Notes shall be issued as Registered Securities in global form without coupons, in substantially the form set out in Exhibit A hereto. The entire initially issued principal amount of the Series C Senior Notes shall initially be evidenced by one or more certificates issued to Cede & Co., as nominee for The Depository Trust Company.

Each Series C Senior Note shall be dated the date of authentication thereof and shall bear interest from the date of original issuance thereof or from the most recent Interest Payment Date to which interest has been paid or duly provided for.

SECTION 102 Definitions. The following defined terms used herein shall, unless the context otherwise requires, have the meanings specified below. Capitalized terms used herein for which no definition is provided herein shall have the meanings set forth in the Base Indenture. Unless the context otherwise requires, any reference to a “Section” refers to a Section of this Tenth Supplemental Indenture.

“Business Day” means a day other than (i) a Saturday or a Sunday, (ii) a day on which banks in New York, New York are authorized or obligated by law or executive order to remain closed or (iii) a day on which the Corporate Trust Office is closed for business.

“Comparable Treasury Issue” means the United States Treasury security selected by an Independent Investment Banker as having a maturity comparable to the remaining term of the Series C Senior Notes to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term in years and months of the Series C Senior Notes.

“Comparable Treasury Price” for any Redemption Date means (i) the average of the Reference Treasury Dealer Quotations for such Redemption Date, after excluding the highest and lowest Reference Treasury Dealer Quotations, or (ii) if the Independent Investment Banker obtains fewer than five such Reference Treasury Dealer Quotations, the average of all such quotations.

“Depositary” has the meaning set forth in Section 105.

“Distribution Compliance Period” has the meaning set forth in Section 204.

“Independent Investment Banker” means Morgan Stanley & Co., LLC and its affiliates or successors, or if such firm is unwilling or unable to serve as such, an independent investment and banking institution of national standing appointed by the Company.

2

“Interest Payment Dates” means June 15 and December 15 of each year, commencing on December 15, 2016.

“Original Issue Date” means June 17, 2016.

“Outstanding,” when used with respect to the Series C Senior Notes, means, as of the date of determination, all Series C Senior Notes theretofore authenticated and delivered under the Indenture, except:

(i) Series C Senior Notes theretofore canceled by the Trustee or delivered to the Trustee for cancellation;

(ii) Series C Senior Notes for whose payment at the Maturity thereof money in the necessary amount has been theretofore deposited (other than pursuant to Section 402 of the Base Indenture) with the Trustee or any Paying Agent (other than the Company) in trust or set aside and segregated in trust by the Company (if the Company shall act as its own Paying Agent) for the Holders of such Series C Senior Notes, provided that, if such Series C Senior Notes are to be redeemed, notice of such redemption has been duly given pursuant to the Indenture or provision therefor satisfactory to the Trustee has been made;

(iii) Series C Senior Notes with respect to which the Company has effected defeasance or covenant defeasance pursuant to Section 402 of the Base Indenture, except to the extent provided in Section 402 of the Base Indenture; and

(iv) Series C Senior Notes that have been paid pursuant to Section 306 of the Base Indenture or in exchange for or in lieu of which other Series C Senior Notes have been authenticated and delivered pursuant to the Indenture, other than any such Series C Senior Notes in respect of which there shall have been presented to the Trustee proof satisfactory to it that such Series C Senior Notes are held by a bona fide purchaser in whose hands such Series C Senior Notes are valid obligations of the Company; provided, however, that in determining whether the Holders of the requisite principal amount of Outstanding Series C Senior Notes have given any request, demand, authorization, direction, notice, consent or waiver under the Indenture or are present at a meeting of Holders of Series C Senior Notes for quorum purposes, Series C Senior Notes owned by the Company or any other obligor upon the Series C Senior Notes or any Affiliate of the Company or such other obligor shall be disregarded and deemed not to be Outstanding, except that, in determining whether the Trustee shall be protected in making any such determination or relying upon any such request, demand, authorization, direction, notice, consent or waiver, only those Series C Senior Notes which a Responsible Officer of the Trustee actually knows to be so owned shall be so disregarded. Series C Senior Notes so owned which shall have been pledged in good faith may be regarded as Outstanding if the pledgee establishes to the satisfaction of the Trustee (a) the pledgee’s right so to act with respect to such Series C Senior Notes and (b) that the pledgee is not the Company or any other obligor upon the Series C Senior Notes or an Affiliate of the Company or such other obligor.

“Primary Treasury Dealer” means a primary United States government securities dealer in the United States as designated by the Federal Reserve Bank of New York.

“QIB” means a “qualified institutional buyer” as defined in Rule 144A.

3

“Reference Treasury Dealer” means (i) Morgan Stanley & Co., LLC and its affiliates or successors; provided that, if such firm or its successors ceases to be a Primary Treasury Dealer, the Company shall substitute another Primary Treasury Dealer; and (ii) up to four (4) other Primary Treasury Dealers selected by the Company.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any Redemption Date, the average, as determined by the Independent Investment Banker, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Independent Investment Banker at 3:30 p.m., New York City time, on the third (3rd) Business Day preceding such Redemption Date.

“Regular Record Date” means, with respect to each Interest Payment Date, the close of business on the Business Day preceding such Interest Payment Date; provided, that with respect to Series C Senior Notes that are not represented by one or more Global Securities, the Regular Record Date shall be the close of business on the fifteenth (15th) calendar day (whether or not a Business Day) preceding such Interest Payment Date.

“Regulation S” means Regulation S promulgated under the Securities Act.

“Regulation S Global Security” has the meaning set forth in Section 105.

“Restricted Legend” has the meaning set forth in Section 202.

“Restricted Security” has the meaning set forth in Section 202.

“Rule 144A” means Rule 144A promulgated under the Securities Act.

“Rule 144A Global Security” has the meaning set forth in Section 105.

“Securities Act” means the Securities Act of 1933, as amended.

“Series C Senior Notes” has the meaning set forth in Section 101.

“Stated Maturity” means June 15, 2023.

“Treasury Rate” means, with respect to any Redemption Date, the rate per annum equal to the semiannual equivalent yield to maturity or interpolated (on a day count basis) of the Comparable Treasury Issue, assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Redemption Date.

The terms “Company,” “Issuer,” “Trustee,” “Base Indenture,” and “Indenture” shall have the respective meanings set forth in the recitals to this Tenth Supplemental Indenture and the paragraph preceding such recitals.

SECTION 103 Payment of Principal and Interest. The principal of the Series C Senior Notes shall be due at the Stated Maturity (unless earlier redeemed). The unpaid principal

4

amount of the Series C Senior Notes shall bear interest at the rate of 2.875% per annum, until paid or duly provided for, such interest to accrue from the Original Issue Date or from the most recent Interest Payment Date to which interest has been paid or duly provided for. Interest shall be paid semi-annually in arrears on each Interest Payment Date to the Person in whose name the Series C Senior Notes are registered on the Regular Record Date for such Interest Payment Date; provided that interest payable at the Stated Maturity of principal or on a Redemption Date as provided herein will be paid to the Person to whom principal is payable. Any such interest that is not so punctually paid or duly provided for will forthwith cease to be payable to the Holders on such Regular Record Date and may either be paid to the Person or Persons in whose name the Series C Senior Notes are registered at the close of business on a Special Record Date for the payment of such defaulted interest to be fixed by the Trustee (in accordance with Section 307 of the Base Indenture), notice whereof shall be given to Holders of the Series C Senior Notes not less than ten (10) days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange, if any, on which the Series C Senior Notes may be listed, and upon such notice as may be required by any such exchange, all as more fully provided in the Base Indenture.

Payments of interest on the Series C Senior Notes will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the Series C Senior Notes shall be computed and paid on the basis of a 360-day year of twelve (12) thirty (30)-day months. In the event that any date on which interest is payable on the Series C Senior Notes is not a Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Payment of the principal and interest on the Series C Senior Notes shall be made at the office of the Paying Agent in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts, with any such payment that is due at the Stated Maturity of any Series C Senior Notes, upon redemption or repurchase being made upon surrender of such Series C Senior Notes to the Paying Agent. Payments of interest (including interest on any Interest Payment Date) will be made, subject to such surrender where applicable, at the option of the Company, (i) by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (ii) by wire transfer at such place and to such account at a banking institution in the United States as may be designated in writing to the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto. In the event that any date on which principal and interest is payable on the Series C Senior Notes is not a Business Day, then payment of the principal and interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

SECTION 104 Denominations . The Series C Senior Notes may be issued in denominations of $2,000, or any greater integral multiple of $1,000.

SECTION 105 Global Securities. The Series C Senior Notes offered and sold to QIBs in reliance on Rule 144A will be initially issued in the form of one or more Global

5

Securities (the “Rule 144A Global Security”), and the Series C Senior Notes offered and sold in offshore transactions to non-U.S. persons in reliance on Regulation S will be initially issued in the form of one or more Global Securities (the “Regulation S Global Security”), in each case registered in the name of the Depositary (which shall be The Depository Trust Company) or its nominee. Except under the limited circumstances described below, Series C Senior Notes represented by such Global Securities will not be exchangeable for, and will not otherwise be issuable as, Series C Senior Notes in definitive form registered in names other than the Depositary or its nominee. The Global Securities described above may not be transferred except by the Depositary to a nominee of the Depositary or by a nominee of the Depositary to the Depositary or another nominee of the Depositary or to a successor Depositary or its nominee.

Owners of beneficial interests in such a Global Security will not be considered the Holders thereof for any purpose under the Indenture, and no Global Security representing a Series C Senior Note shall be exchangeable, except for another Global Security of like denomination and tenor to be registered in the name of the Depositary or its nominee or to a successor Depositary or its nominee or except as described below. The rights of Holders of such Global Security shall be exercised only through the Depositary.

A Global Security shall be exchangeable for Series C Senior Notes registered in the names of persons other than the Depositary or its nominee only if (i) the Depositary notifies the Company that it is unwilling or unable to continue as a Depositary for such Global Security and no successor Depositary shall have been appointed by the Company within ninety (90) days of receipt by the Company of such notification, or if at any time the Depositary ceases to be a clearing agency registered under the Exchange Act at a time when the Depositary is required to be so registered to act as such Depositary and no successor Depositary shall have been appointed by the Company within ninety (90) days after it becomes aware of such cessation, (ii) the Company in its sole discretion, and subject to the procedures of the Depositary, determines that such Global Security shall be so exchangeable, in which case Series C Senior Notes in definitive form will be printed and delivered to the Depositary, or (iii) an Event of Default has occurred and is continuing with respect to the Series C Senior Notes. Any Global Security that is exchangeable pursuant to the preceding sentence shall be exchangeable for Series C Senior Notes registered in such names as the Depositary shall direct.

SECTION 106 Redemption. The Series C Senior Notes are redeemable, in whole or in part at any time and from time to time, at the option of the Company, at a Redemption Price equal to the greater of:

(a) 100% of the principal amount of Series C Senior Notes then Outstanding to be redeemed, or

(b) the sum of the present values of the remaining scheduled payments of principal and interest on the Series C Senior Notes to be redeemed (not including any portion of such payments of interest accrued as of the Redemption Date) discounted to the Redemption Date on a semi-annual basis (assuming a 360-day year consisting of twelve (12) thirty (30)-day months) at the Treasury Rate, plus 25 basis points, as calculated by an Independent Investment Banker,

6

plus, in either of the above cases, accrued and unpaid interest thereon to the Redemption Date.

The Treasury Rate shall be calculated on the third (3rd) Business Day preceding the Redemption Date.

Unless the Company defaults in the payment of the Redemption Price, on and after the Redemption Date, interest will cease to accrue on the Series C Senior Notes or portions thereof called for redemption.

In the event of the redemption of the Series C Senior Notes in part only, a new Series C Senior Note or Notes for the unredeemed portion will be issued in the name or names of the Holders thereof upon surrender thereof.

The Company shall notify the Trustee of the Redemption Price in writing promptly after the calculation thereof and the Trustee shall have no responsibility for such calculation. Notices of redemption shall be mailed by first-class mail to each Holder of Series C Senior Notes to be redeemed at its registered address, or delivered electronically to the e-mail address, if any, provided to the Security Registrar by the Holder for such purpose.

SECTION 107 Sinking Fund; Conversion. The Series C Senior Notes shall not have a sinking fund. The Series C Senior Notes are not convertible into or exchangeable for Equity Securities or any other securities.

SECTION 108 Additional Interest on Overdue Amounts. Any principal of and installment of interest on the Series C Senior Notes that is overdue shall bear interest at the rate of 2.875% per annum (to the extent that the payment of such interest shall be legally enforceable), from the dates such amounts are due until they are paid or made available for payment, and such interest shall be payable on demand.

SECTION 109 Paying Agent; Security Registrar. The Trustee shall initially serve as Paying Agent and Security Registrar with respect to the Series C Senior Notes, with the Place of Payment initially being the Corporate Trust Office. The Company may change the Paying Agent or Security Registrar without prior notice to Holders of the Series C Senior Notes, and the Company or any of its subsidiaries may act as Paying Agent or Security Registrar.

ARTICLE II

TRANSFER AND EXCHANGE

SECTION 201 Transfer and Exchange of Global Securities. The transfer and exchange of beneficial interests in the Global Securities shall be effected through the Depositary, in accordance with this Tenth Supplemental Indenture (including applicable restrictions on transfer set forth herein, if any) and the procedures of the Depositary therefor.

SECTION 202 Restricted Legend. Except as otherwise provided in Section 203 and as indicated on Exhibit A, each Series C Senior Note (each a “Restricted Security”) shall bear the following legend (the “Restricted Legend”) on the face thereof:

7

THIS SERIES C SENIOR NOTE (OR ITS PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION EXEMPT FROM REGISTRATION UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), AND THIS SERIES C SENIOR NOTE MAY NOT BE OFFERED, SOLD OR OTHERWISE TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION THEREFROM. EACH PURCHASER OF THIS SERIES C SENIOR NOTE IS HEREBY NOTIFIED THAT THE SELLER OF THIS SERIES C SENIOR NOTE MAY BE RELYING ON THE EXEMPTION FROM THE PROVISIONS OF SECTION 5 OF THE SECURITIES ACT PROVIDED BY RULE 144A THEREUNDER.

THE HOLDER OF THIS SERIES C SENIOR NOTE AGREES FOR THE BENEFIT OF THE COMPANY THAT (A) THIS SERIES C SENIOR NOTE MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE TRANSFERRED, ONLY (I) IN THE UNITED STATES TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A QUALIFIED INSTITUTIONAL BUYER (AS DEFINED IN RULE 144A UNDER THE SECURITIES ACT) IN A TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (II) OUTSIDE THE UNITED STATES IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH RULE 904 UNDER THE SECURITIES ACT, (III) PURSUANT TO AN EXEMPTION FROM REGISTRATION UNDER THE SECURITIES ACT PROVIDED BY RULE 144 THEREUNDER (IF AVAILABLE), (IV) PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE SECURITIES ACT, OR (V) TO AN INSTITUTIONAL “ACCREDITED INVESTOR” (AS DEFINED IN RULE 501(A)(1), (2), (3) OR (7) OF REGULATION D UNDER THE SECURITIES ACT) THAT IS ACQUIRING THE NOTE FOR ITS OWN ACCOUNT, OR FOR THE ACCOUNT OF SUCH AN INSTITUTIONAL “ACCREDITED INVESTOR” FOR INVESTMENT PURPOSES AND NOT WITH A VIEW TO, OR FOR OFFER OR SALE IN CONNECTION WITH, ANY DISTRIBUTION IN VIOLATION OF THE SECURITIES ACT, IN EACH OF CASES (I) THROUGH (V) IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY STATE OF THE UNITED STATES, AND (B) THE HOLDER WILL, AND EACH SUBSEQUENT HOLDER IS REQUIRED TO, NOTIFY ANY PURCHASER OF THIS SERIES C SENIOR NOTE FROM IT OF THE RESALE RESTRICTIONS REFERRED TO IN CLAUSE (A) ABOVE.

THE HOLDER AGREES THAT IT WILL DELIVER TO EACH PERSON TO WHOM THIS SERIES C SENIOR NOTE OR AN INTEREST HEREIN IS TRANSFERRED A NOTICE SUBSTANTIALLY TO THE EFFECT OF THIS LEGEND.

THE HOLDER AGREES THAT, BEFORE THE HOLDER OFFERS, SELLS OR OTHERWISE TRANSFERS THIS SERIES C SENIOR NOTE, THE COMPANY MAY REQUIRE THE HOLDER OF THIS SERIES C SENIOR NOTE TO DELIVER A WRITTEN OPINION, CERTIFICATIONS AND/OR OTHER INFORMATION THAT IT REASONABLY REQUIRES TO CONFIRM THAT SUCH PROPOSED TRANSFER IS BEING MADE PURSUANT TO AN EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE UNITED STATES.

AS USED IN THIS SERIES C SENIOR NOTE, THE TERMS “OFFSHORE TRANSACTION,” “U.S. PERSON” AND “UNITED STATES” HAVE THE MEANINGS GIVEN TO THEM BY RULE 902 OF REGULATION S UNDER THE SECURITIES ACT.

8

SECTION 203 Removal of Restricted Legend. The Company may instruct the Trustee in writing to cancel any Series C Senior Note and, upon receipt of a Company Order, authenticate a replacement Series C Senior Note, registered in the name of the Holder thereof (or its transferee), that does not bear the Restricted Legend, and the Trustee will comply with such instruction, if the Company determines (upon the advice of counsel and such other certifications and evidence as the Company may reasonably require) that a Series C Senior Note is eligible for resale pursuant to Rule 144 under the Securities Act (or a successor provision) and that the Restricted Legend is no longer necessary or appropriate in order to ensure that subsequent transfers of such Series C Senior Note (or a beneficial interest therein) are effected in compliance with the Securities Act; provided, however, that in such circumstances, the Trustee shall require an Opinion of Counsel and an Officers’ Certificate prior to authenticating any such replacement Series C Senior Note.

SECTION 204 Registration of Transfer or Exchange. The registration of transfer or exchange of any Series C Senior Note (or a beneficial interest therein) that bears the Restricted Legend may only be made in compliance with the provisions of the Restricted Legend and as set forth below.

(i) Prior to and including the fortieth (40th) day after the later of the commencement of the offering of the Series C Senior Notes and the Original Issue Date (such period through and including such fortieth (40th) day, the “Distribution Compliance Period”), transfers by an owner of a beneficial interest in a Regulation S Global Security to a transferee who takes delivery of such interest through a Rule 144A Global Security of that series will be made only upon receipt by the Trustee of a written certification from the transferor of the beneficial interest to the effect that such transfer is being made to a Person whom the transferor reasonably believes is purchasing for its own account or accounts as to which it exercises sole investment discretion and is a QIB in a transaction meeting the requirements of Rule 144A and the requirements of applicable securities laws of any state of the United States or any other jurisdiction.

(ii) Transfers by an owner of a beneficial interest in the Rule 144A Global Security to a transferee who takes delivery through the Regulation S Global Security of that series, whether before or after the expiration of the Distribution Compliance Period, will be made only upon receipt by the Trustee of a certification from the transferor to the effect that such transfer is being made in accordance with Rule 904 of Regulation S or Rule 144 under the Securities Act and that, if such transfer is being made prior to the expiration of the Distribution Compliance Period, the interest transferred will be held immediately thereafter through Euroclear Bank S.A./N.V., as operator of the Euroclear System or Clearstream Banking, société anonyme, Luxembourg.

(iii) Any beneficial interest in one of the Global Securities that is transferred to a Person who takes delivery in the form of an interest in another Global Security of that series will, upon transfer, cease to be an interest in the initial Global Security of that series and will become an interest in the other Global Security of that series and, accordingly, will thereafter be subject to all transfer restrictions, if any, and other procedures applicable to beneficial interests in such other Global Security of that series for as long as it remains such an interest.

9

SECTION 205 Preservation of Information. The Trustee will retain copies of all certificates, opinions and other documents received in connection with the registration of transfer or exchange of a Series C Senior Note (or a beneficial interest therein) in accordance with its customary policy, and the Company will have the right to request copies thereof at any reasonable time upon written notice to the Trustee.

SECTION 206 Acknowledgment of Restrictions; Indemnification; No Obligation of Trustee. By its acceptance of any Series C Senior Note bearing the Restricted Legend, each Holder of such a Series C Senior Note acknowledges the restrictions on registrations of transfer or exchange of such Series C Senior Note set forth in this Tenth Supplemental Indenture and in the Restricted Legend and agrees that it will register the transfer or exchange of such Series C Senior Note only as provided in this Tenth Supplemental Indenture. The Security Registrar shall not register a transfer or exchange of any Series C Senior Note unless such transfer or exchange complies with the restrictions on transfer or exchange of such Series C Senior Note set forth in this Tenth Supplemental Indenture. In connection with any registration of transfer or exchange of Series C Senior Notes, each Holder agrees by its acceptance of the Series C Senior Notes to furnish the Security Registrar or the Company such certifications, legal opinions or other information as either of them may reasonably require to confirm that such registration of transfer or exchange is being made pursuant to an exemption from, or a transaction not subject to, the registration requirements of the Securities Act; provided that the Security Registrar shall not be required to determine (but may rely on a determination made by the Company with respect to) the sufficiency of any such certifications, legal opinions or other information.

The Security Registrar shall retain copies of all letters, notices and other written communications received pursuant to the Indenture in accordance with its customary policy. The Company shall have the right to request copies of all such letters, notices or other written communications at any reasonable time upon the giving of written notice to the Security Registrar.

Each Holder of a Series C Senior Note agrees to indemnify the Company, the Security Registrar and the Trustee against any liability that may result from the transfer, exchange or assignment of such Holder’s Series C Senior Note in violation of any provision of this Tenth Supplemental Indenture and/or applicable United States Federal or state securities law.

The Trustee shall have no obligation or duty to monitor, determine or inquire as to compliance with any restrictions on transfer or exchange imposed under this Tenth Supplemental Indenture or under applicable law with respect to any registrations of transfer or exchange of any interest in any Series C Senior Note (including any transfers between or among members of, or participants in, the Depositary or beneficial owners of interests in any Global Security) other than to require delivery of such certificates and other documentation or evidence as are expressly required by, and to do so if and when expressly required by the terms of, this Tenth Supplemental Indenture, and to examine the same to determine substantial compliance as to form with the express requirements hereof.

10

ARTICLE III

MISCELLANEOUS PROVISIONS

SECTION 301 Ratification and Incorporation of Base Indenture. As supplemented hereby, the Base Indenture is in all respects ratified and confirmed by the Company, and the Base Indenture and this Tenth Supplemental Indenture shall be read, taken and construed as one and the same instrument.

SECTION 302 Executed in Counterparts. This Tenth Supplemental Indenture may be executed in several counterparts, each of which shall be deemed to be an original, and such counterparts shall together constitute but one and the same instrument. The exchange of copies of this Tenth Supplemental Indenture and of signature pages by facsimile or PDF transmission shall constitute effective execution and delivery of this Tenth Supplemental Indenture as to the parties hereto and may be used in lieu of the original, manually executed Tenth Supplemental Indenture for all purposes. Signatures of the parties hereto transmitted by facsimile or PDF shall be deemed to be their original signatures for all purposes.

SECTION 303 Assignment. The Company shall have the right at all times to assign any of its rights or obligations under the Indenture with respect to the Series C Senior Notes to a direct or indirect wholly owned subsidiary of the Company; provided that, in the event of any such assignment, the Company shall remain primarily liable for the performance of all such obligations. The Indenture may also be assigned by the Company in connection with a transaction described in Article VIII of the Base Indenture.

SECTION 304 Trustee’s Disclaimer. All of the provisions contained in the Base Indenture in respect of the rights, powers, privileges, protections, duties and immunities of the Trustee, including without limitation its right to be indemnified, shall be applicable in respect of the Series C Senior Notes and of this Tenth Supplemental Indenture as fully and with like effect as if set forth herein in full. The Trustee accepts the amendments of the Indenture effected by this Tenth Supplemental Indenture, but on the terms and conditions set forth in the Indenture, including the terms and provisions defining and limiting the liabilities and responsibilities of the Trustee. Without limiting the generality of the foregoing, the Trustee shall not be responsible in any manner whatsoever for or with respect to any of the recitals or statements contained herein, all of which recitals or statements are made solely by the Company, or for or with respect to (i) the validity or sufficiency of this Tenth Supplemental Indenture or any of the terms or provision hereof, (ii) the proper authorization hereof by the Company by action or otherwise, (iii) the due execution hereof by the Company, or (iv) the consequences of any amendment herein provided for, and the Trustee makes no representation with respect to any such matters.

[Signature Page Follows]

11

IN WITNESS WHEREOF, each party hereto has caused this instrument to be signed in its name and behalf by its duly authorized officer, all as of the day and year first above written.

DOMINION GAS HOLDINGS, LLC
By:	/s/ James R. Chapman
Name:	James R. Chapman
Title:	Senior Vice President – Mergers &
	Acquisitions and Treasurer
DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:	/s/ Carol Ng
Name:	Carol Ng
Title:	Vice President
By:	/s/ Deirdra N. Ross
Name:	Deirdra N. Ross
Title:	Vice President

12

EXHIBIT A

FORM OF

2016 SERIES C 2.875% SENIOR NOTE

DUE 2023

[UNLESS THIS CERTIFICATE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY (55 WATER STREET, NEW YORK, NEW YORK) TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY CERTIFICATE ISSUED IS REGISTERED IN THE NAME OF [CEDE & CO.] OR SUCH OTHER NAME AS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF THE DEPOSITORY TRUST COMPANY AND ANY PAYMENT IS MADE TO [CEDE & CO.], ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL SINCE THE REGISTERED OWNER HEREOF, [CEDE & CO.], HAS AN INTEREST HEREIN.]**

[THIS SERIES C SENIOR NOTE IS A GLOBAL SECURITY WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR A NOMINEE THEREOF. THIS SERIES C SENIOR NOTE MAY NOT BE EXCHANGED IN WHOLE OR IN PART FOR A SECURITY REGISTERED, AND NO TRANSFER OF THIS SERIES C SENIOR NOTE IN WHOLE OR IN PART MAY BE REGISTERED, IN THE NAME OF ANY PERSON OTHER THAN SUCH DEPOSITARY OR A NOMINEE THEREOF, EXCEPT IN THE LIMITED CIRCUMSTANCES DESCRIBED IN THE INDENTURE. EVERY SERIES C SENIOR NOTE AUTHENTICATED AND DELIVERED UPON REGISTRATION OF, TRANSFER OF, OR IN EXCHANGE FOR OR IN LIEU OF, THIS SERIES C SENIOR NOTE SHALL BE A GLOBAL SECURITY SUBJECT TO THE FOREGOING, EXCEPT IN SUCH LIMITED CIRCUMSTANCES.]***

[THIS SERIES C SENIOR NOTE (OR ITS PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION EXEMPT FROM REGISTRATION UNDER THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED (THE “SECURITIES ACT”), AND THIS SERIES C SENIOR NOTE MAY NOT BE OFFERED, SOLD OR OTHERWISE TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION THEREFROM. EACH PURCHASER OF THIS SERIES C SENIOR NOTE IS HEREBY NOTIFIED THAT THE SELLER OF THIS SERIES C SENIOR NOTE MAY BE RELYING ON THE EXEMPTION FROM THE PROVISIONS OF SECTION 5 OF THE SECURITIES ACT PROVIDED BY RULE 144A THEREUNDER.]****

[THE HOLDER OF THIS SERIES C SENIOR NOTE AGREES FOR THE BENEFIT OF THE COMPANY THAT (A) THIS SERIES C SENIOR NOTE MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE TRANSFERRED, ONLY (I) IN THE UNITED

*** Insert in Global Securities.

**** Insert in Restricted Securities

A-1

STATES TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A QUALIFIED INSTITUTIONAL BUYER (AS DEFINED IN RULE 144A UNDER THE SECURITIES ACT) IN A TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (II) OUTSIDE THE UNITED STATES IN AN OFFSHORE TRANSACTION IN ACCORDANCE WITH RULE 904 UNDER THE SECURITIES ACT, (III) PURSUANT TO AN EXEMPTION FROM REGISTRATION UNDER THE SECURITIES ACT PROVIDED BY RULE 144 THEREUNDER (IF AVAILABLE), (IV) PURSUANT TO AN EFFECTIVE REGISTRATION STATEMENT UNDER THE SECURITIES ACT, OR (V) TO AN INSTITUTIONAL “ACCREDITED INVESTOR” (AS DEFINED IN RULE 501(A)(1), (2), (3) OR (7) OF REGULATION D UNDER THE SECURITIES ACT) THAT IS ACQUIRING THE NOTE FOR ITS OWN ACCOUNT, OR FOR THE ACCOUNT OF SUCH AN INSTITUTIONAL “ACCREDITED INVESTOR” FOR INVESTMENT PURPOSES AND NOT WITH A VIEW TO, OR FOR OFFER OR SALE IN CONNECTION WITH, ANY DISTRIBUTION IN VIOLATION OF THE SECURITIES ACT, IN EACH OF CASES (I) THROUGH (V) IN ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY STATE OF THE UNITED STATES, AND (B) THE HOLDER WILL, AND EACH SUBSEQUENT HOLDER IS REQUIRED TO, NOTIFY ANY PURCHASER OF THIS SERIES C SENIOR NOTE FROM IT OF THE RESALE RESTRICTIONS REFERRED TO IN CLAUSE (A) ABOVE.]***

[THE HOLDER AGREES THAT IT WILL DELIVER TO EACH PERSON TO WHOM THIS SERIES C SENIOR NOTE OR AN INTEREST HEREIN IS TRANSFERRED A NOTICE SUBSTANTIALLY TO THE EFFECT OF THIS LEGEND.]***

[THE HOLDER AGREES THAT, BEFORE THE HOLDER OFFERS, SELLS OR OTHERWISE TRANSFERS THIS SERIES C SENIOR NOTE, THE COMPANY MAY REQUIRE THE HOLDER OF THIS SERIES C SENIOR NOTE TO DELIVER A WRITTEN OPINION, CERTIFICATIONS AND/OR OTHER INFORMATION THAT IT REASONABLY REQUIRES TO CONFIRM THAT SUCH PROPOSED TRANSFER IS BEING MADE PURSUANT TO AN EXEMPTION FROM THE REGISTRATION REQUIREMENTS OF THE UNITED STATES.]***

[AS USED IN THIS SERIES C SENIOR NOTE, THE TERMS “OFFSHORE TRANSACTION,” “U.S. PERSON” AND “UNITED STATES” HAVE THE MEANINGS GIVEN TO THEM BY RULE 902 OF REGULATION S UNDER THE SECURITIES ACT.]***

A-2

DOMINION GAS HOLDINGS, LLC

[Up to]** $[                ]

2016 SERIES C 2.875% SENIOR NOTE

DUE 2023

No. R-             CUSIP No.                

Dominion Gas Holdings, LLC, a limited liability company duly organized and existing under the laws of Virginia (herein called the “Company” or “Issuer”, which terms include any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to [Cede & Co.]**, or registered assigns (the “Holder”), the principal sum [of             Dollars ($            )] [subject to the increases and decreases set forth in Schedule I hereto]** on June 15, 2023 and to pay interest thereon from June 17, 2016 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, semi-annually in arrears on June 15 and December 15 of each year, commencing on December 15, 2016, at the rate of 2.875% per annum, until the principal hereof is paid or made available for payment, provided that any principal, and any such installment of interest, that is overdue shall bear interest at the rate of 2.875% per annum (to the extent that the payment of such interest shall be legally enforceable), from the dates such amounts are due until they are paid or made available for payment, and such interest shall be payable on demand. The interest so payable, and punctually paid or duly provided for, on any Interest Payment Date will, as provided in such Indenture, be paid to the Person in whose name this Series C Senior Note (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date for such interest; provided that the interest payable at Stated Maturity or on a Redemption Date will be paid to the Person to whom principal is payable. The Regular Record Date shall be the close of business on the Business Day preceding such Interest Payment Date; provided, that with respect to Series C Senior Notes that are not represented by one or more Global Securities, the Regular Record Date shall be the close of business on the fifteenth (15th) calendar day (whether or not a Business Day) preceding such Interest Payment Date. Any such interest not so punctually paid or duly provided for will forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Series C Senior Note (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice whereof shall be given to Holders of Series C Senior Notes not less than ten (10) days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Series C Senior Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.

Payments of interest on the Series C Senior Notes will include interest accrued to but excluding the respective Interest Payment Dates. Interest payments for the Series C Senior Notes shall be computed and paid on the basis of a 360-day year of twelve (12) thirty (30)-day months. In the event that any date on which interest is payable on the Series C Senior Notes is not a

A-3

Business Day, then payment of the interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Payment of the principal of and interest on this Series C Senior Note will be made at the office of the Paying Agent, in the Borough of Manhattan, City and State of New York, in such coin or currency of the United States of America as at the time of payment is legal tender for payment of public and private debts, with any such payment that is due at the Stated Maturity of any Series C Senior Note, upon redemption or repurchase being made upon surrender of such Series C Senior Note to such office or agency; provided, however, that at the option of the Company payment of interest, subject to such surrender where applicable, may be made (i) by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register or (ii) by wire transfer at such place and to such account at a banking institution in the United States as may be designated in writing to the Trustee at least sixteen (16) days prior to the date for payment by the Person entitled thereto. In the event that any date on which principal and interest is payable on the Series C Senior Notes is not a Business Day, then payment of the principal and interest payable on such date will be made on the next succeeding day that is a Business Day (and without any interest or payment in respect of any such delay), in each case with the same force and effect as if made on the date the payment was originally payable.

Reference is hereby made to the further provisions of this Series C Senior Note set forth on the reverse hereof, which further provisions shall for all purposes have the same effect as if set forth at this place.

Unless the certificate of authentication hereon has been executed by the Trustee referred to on the reverse hereof by manual signature, this Series C Senior Note shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

A-4

IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.

Dated:	DOMINION GAS HOLDINGS, LLC
	By:
	Name:
	Title:

TRUSTEE’S CERTIFICATE OF AUTHENTICATION

This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.

DEUTSCHE BANK TRUST COMPANY AMERICAS, as Trustee
By:
	Authorized Signatory
Dated:

A-5

[REVERSE OF 2016 SERIES C 2.875% SENIOR NOTE]

This Security is one of a duly authorized issue of securities of the Company (herein called the “Securities”), issued and to be issued in one or more series under an Indenture dated as of October 1, 2013 (the “Base Indenture”), among the Company and Deutsche Bank Trust Company Americas, as Trustee (the “Trustee”), as heretofore supplemented and as further supplemented by a Tenth Supplemental Indenture dated as of June 1, 2016 (the “Tenth Supplemental Indenture” and, together with the Base Indenture, as it may be hereafter supplemented or amended from time to time, the “Indenture,” which term shall have the meaning assigned to it in such instrument), by and between the Company and the Trustee, and reference is hereby made to the Indenture for a statement of the respective rights, limitations of rights, duties and immunities thereunder of the Company, the Trustee and the Holders of the Securities and of the terms upon which the Securities are, and are to be, authenticated and delivered. This Security is one of the series designated on the face hereof (the “Series C Senior Notes”) which is unlimited in aggregate principal amount.

The Series C Senior Notes are redeemable, in whole or in part, at any time and from time to time, in the manner and with the effect provided in the Indenture.

If an Event of Default with respect to Series C Senior Notes shall occur and be continuing, the principal of the Series C Senior Notes may be declared due and payable in the manner and with the effect provided in the Indenture.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Securities of each series to be affected under the Indenture at any time by the Company and the Trustee for the series of Securities affected, with the consent of the Holders of a majority in principal amount of the Securities at the time Outstanding of each series to be affected. The Indenture also contains provisions permitting the Holders of specified percentages in principal amount of the Securities of each series at the time Outstanding, on behalf of the Holders of all Securities of such series, to waive certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Series C Senior Note shall be conclusive and binding upon such Holder and upon all future Holders of this Series C Senior Note and of any Series C Senior Note issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Series C Senior Note.

As provided in and subject to the provisions of the Indenture, the Holder of this Series C Senior Note shall not have the right to institute any proceeding with respect to the Indenture or for the appointment of a receiver or trustee or for any other remedy thereunder, unless such Holder shall have previously given the Trustee written notice of a continuing Event of Default with respect to the Series C Senior Notes, the Holders of not less than a majority in principal amount of the Series C Senior Notes at the time Outstanding shall have made written request to the Trustee to institute proceedings in respect of such Event of Default as Trustee and offered the Trustee indemnity or security reasonably satisfactory to it, and the Trustee shall not have received from the Holders of a majority in principal amount of Series C Senior Notes at the time Outstanding a direction inconsistent with such request, and shall have failed to institute any such

A-6

proceeding for sixty (60) days after receipt of such notice, request and offer of indemnity. The foregoing shall not apply to any suit instituted by the Holder of this Series C Senior Note for the enforcement of any payment of principal hereof or premium, if any, or interest hereon on or after the respective due dates expressed or provided for herein.

No reference herein to the Indenture and no provision of this Series C Senior Note or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of, premium, if any, and interest on this Series C Senior Note at the times, place and rate, and in the coin or currency, herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Series C Senior Note is registrable in the Security Register, upon surrender of this Series C Senior Note for registration of transfer at the office or agency of the Company in any place where the principal of, premium, if any, and interest on this Series C Senior Note are payable, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Series C Senior Notes of like tenor, of authorized denominations and for the same aggregate principal amount, will be issued to the designated transferee or transferees.

The Series C Senior Notes are issuable only in registered form without coupons in denominations of $2,000 and any greater integral multiple of $1,000. As provided in the Indenture and subject to certain limitations therein set forth, Series C Senior Notes are exchangeable for a like aggregate principal amount of Series C Senior Notes having the same Stated Maturity and of like tenor of any authorized denominations as requested by the Holder upon surrender of the Series C Senior Note or Series C Senior Notes to be exchanged at the office or agency of the Company.

No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.

Prior to due presentment of this Series C Senior Note for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the owner hereof for all purposes, whether or not this Series C Senior Note be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.

All terms used in this Series C Senior Note that are defined in the Indenture shall have the meanings assigned to them in the Indenture.

A-7

ABBREVIATIONS

The following abbreviations, when used in the inscription on the face of this instrument, shall be construed as though they were written out in full according to applicable laws or regulations:

TEN COM -	as tenants in common
TEN ENT -	as tenants by the entireties
JT TEN -	as joint tenants with rights of survivorship and not as tenants in common
UNIF GIFT MIN ACT -	Custodian for
	(Cust)
	(Minor)
	Under Uniform Gifts to Minors Act of
	(State)

Additional abbreviations may also be used though not on the above list.

A-8

FOR VALUE RECEIVED, the undersigned hereby sell(s) and transfer(s) unto

.

(please insert Social Security or other identifying number of assignee)

.

.

.

PLEASE PRINT OR TYPEWRITE NAME AND ADDRESS, INCLUDING POSTAL ZIP CODE OF ASSIGNEE

the within Series C Senior Note and all rights thereunder, hereby irrevocably constituting and appointing

.

.

.

.

.

.

agent to transfer said Series C Senior Note on the books of the Company, with full power of substitution in the premises.

Dated:                                        ,                 

NOTICE: The signature to this assignment must correspond with the name as written upon the face of the within instrument in every particular without alteration or enlargement, or any change whatever.

A-9

DOMINION GAS HOLDINGS, LLC

2016 SERIES C SENIOR NOTE

DUE 2023

No. R-     

SCHEDULE I**

The initial principal amount of this Series C Senior Note is: $                

The following increases or decreases in this Global Security have been made:

Date of increase or decrease and reason for the change in principal amount Amount of decrease in principal amount of this Global Security Amount of increase in principal amount of this Global Security Principal amount of this Global Security following such decrease or increase Signature of authorized signatory of Trustee

A-10

EX-12.1

Exhibit 12.1

Dominion Resources, Inc. and Subsidiaries

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

						Years Ended December 31,
	Six Months Ended June 30, 2016(a)			Twelve Months Ended June 30, 2016(b)		2015(c)		2014(d)			2013(e)		2012(f)			2011(g)
Earnings, as defined:
Income from continuing operations including noncontrolling interest before income tax expense	$	1,324		$	2,705	$	2,828	$	1,778		$	2,704	$	2,265		$	2,262
Distributed income from unconsolidated investees, less equity in earnings		(3	)		24		12		(8	)		17		(13	)		(23	)
Fixed charges included in income		491			976		953		1,237			930		880			867
Total earnings, as defined	$	1,812		$	3,705	$	3,793	$	3,007		$	3,651	$	3,132		$	3,106
Fixed charges, as defined:
Interest charges	$	474		$	942	$	920	$	1,208		$	899	$	845		$	818
Rental interest factor		17			34		33		29			31		35			49
Fixed charges included in income	$	491		$	976	$	953	$	1,237		$	930	$	880		$	867
Preference security dividend requirement of consolidated subsidiary		—			—		—		17			25		25			25
Capitalized Interest		59			100		67		39			28		24			11
Interest from discontinued operations		—			—		—		—			85		80			99
Total fixed charges, as defined	$	550		$	1,076	$	1,020	$	1,293		$	1,068	$	1,009		$	1,002
Ratio of Earnings to Fixed Charges		3.29			3.44		3.72		2.33			3.42		3.10			3.10

(a) Earnings for the six months ended June 30, 2016 include $65 million charge associated with an organizational design initiative; and $1 million net charge related to other items. Excluding the effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the six months ended June 30, 2016.

(b) Earnings for the twelve months ended June 30, 2016 include $65 million charge associated with an organizational design initiative; $54 million charge associated with ash pond and landfill closure costs; and $63 million net charge related to other items. Excluding the effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended June 30, 2016.

(c) Earnings for the twelve months ended December 31, 2015 include $85 million write-off of prior-period deferred fuel costs associated with Virginia legislation; $99 million charge associated ash pond and landfill closure costs; $78 million charge related to other items; partially offset by $60 million of net gain related to our investments in nuclear decommissioning trust funds. Excluding the effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2015.

(d) Earnings for the twelve months ended December 31, 2014 include $374 million charge related to North Anna and offshore wind facilities; $284 million charge associated with our liability management effort, which is included in fixed charges; $121 million accrued charge associated with ash pond and landfill closure costs; $93 million charge related to other items; partially offset by $100 million net gain on the sale of our electric retail energy marketing business and $72 million of net gain related to our investments in nuclear decommissioning trust funds. Excluding the effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2014.

(e) Earnings for the twelve months ended December 31, 2013 include a $55 million impairment charge related to certain natural gas infrastructure assets; $40 million charge in connection with the Virginia Commission’s final ruling associated with its biennial review of Virginia Power’s base rates for 2011-2012 test years; $28 million charge associated with our operating expense reduction initiative, primarily reflecting severance pay and other employee related costs; $26 million charge related to the expected early shutdown of certain coal-fired generating units; $29 million charge related to other items ; partially

offset by $81 million of net gain related to our investments in nuclear decommissioning trust funds; $47 million benefit due to a downward revision in the nuclear decommissioning asset retirement obligations for certain merchant nuclear units that are no longer in service; $29 million net benefit primarily resulting from the sale of Elwood. Excluding the net effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2013.

(f) Earnings for the twelve months ended December 31, 2012 include $438 million of impairment and other charges related the planned shut-down of Kewaunee; $87 million of restoration costs associated with severe storms affecting our Dominion Virginia Power and Dominion North Carolina service territories; partially offset by a $36 million net gain related to our investments in nuclear decommissioning trust funds and $4 million net benefit related to other items. Excluding the net effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2012.

(g) Earnings for the twelve months ended December 31, 2011 include $228 million of impairment charges related to electric utility generation assets; $96 million of restoration costs associated with Hurricane Irene; $43 million impairment of excess emission allowances resulting from a new EPA Air Pollution Rule; $31 million net charge in connection with the Virginia State Corporation Commission’s final ruling associated with its biennial review of Virginia Power’s base rates for 2009 and 2010 test years; $21 million of earthquake related costs, largely related to inspections following the safe shutdown of reactors at our North Anna nuclear power station; and a $45 million net charge related to other items; partially offset by a $24 million benefit related to litigation with the Department of Energy for spent nuclear fuel-related costs at our Millstone nuclear power station. Excluding the net effect of these items from the calculation would result in a higher ratio of earnings to fixed charges for the twelve months ended December 31, 2011.

EX-12.2

Exhibit 12.2

Virginia Electric and Power Company

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

					Years Ended December 31,
	Six Months Ended June 30, 2016		Twelve Months Ended June 30, 2016		2015		2014		2013		2012		2011
Earnings, as defined:
Income from continuing operations before income tax expense	$	874	$	1,794	$	1,746	$	1,406	$	1,797	$	1,703	$	1,362
Fixed charges included in income		242		485		474		438		401		418		361
Total earnings, as defined	$	1,116	$	2,279	$	2,220	$	1,844	$	2,198	$	2,121	$	1,723
Fixed charges, as defined:
Interest charges	$	234	$	468	$	457	$	425	$	388	$	404	$	346
Rental interest factor		8		17		17		13		13		14		15
Total fixed charges, as defined	$	242	$	485	$	474	$	438	$	401	$	418	$	361
Ratio of Earnings to Fixed Charges		4.61		4.70		4.68		4.21		5.48		5.07		4.77

EX-12.3

Exhibit 12.3

Dominion Gas Holdings, LLC

Computation of Ratio of Earnings to Fixed Charges

(millions of dollars)

					Years Ended December 31,
	Six Months Ended June 30, 2016		Twelve Months Ended June 30, 2016		2015			2014			2013			2012		2011
Earnings, as defined:
Income from continuing operations before income tax expense	$	331	$	668	$	740		$	846		$	762		$	747	$	549
Distributed income from unconsolidated investees, less equity in earnings		2		1		(3	)		(1	)		(2	)		2		2
Fixed charges included in income		52		97		86			39			43			65		64
Total earnings, as defined	$	385	$	766	$	823		$	884		$	803		$	814	$	615
Fixed charges, as defined:
Interest charges	$	46	$	85	$	74		$	28		$	30		$	51	$	51
Rental interest factor		6		12		12			11			13			14		13
Total fixed charges, as defined	$	52	$	97	$	86		$	39		$	43		$	65	$	64
Ratio of Earnings to Fixed Charges		7.40		7.90		9.57			22.67			18.67			12.52		9.61

EX-31.A

Exhibit 31.a

I, Thomas F. Farrell II, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Resources, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2016	/s/ Thomas F. Farrell II
	Thomas F. Farrell II President and Chief Executive Officer

EX-31.B

Exhibit 31.b

I, Mark F. McGettrick, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Resources, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2016	/s/ Mark F. McGettrick
	Mark F. McGettrick Executive Vice President and Chief Financial Officer

EX-31.C

Exhibit 31.c

I, Thomas F. Farrell II, certify that:

1. I have reviewed this report on Form 10-Q of Virginia Electric and Power Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2016	/s/ Thomas F. Farrell II
	Thomas F. Farrell II Chief Executive Officer

EX-31.D

Exhibit 31.d

I, Mark F. McGettrick, certify that:

1. I have reviewed this report on Form 10-Q of Virginia Electric and Power Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2016	/s/ Mark F. McGettrick
	Mark F. McGettrick Executive Vice President and Chief Financial Officer

EX-31.E

Exhibit 31.e

I, Thomas F. Farrell II, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Gas Holdings, LLC;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2016	/s/ Thomas F. Farrell II
	Thomas F. Farrell II Chief Executive Officer

EX-31.F

Exhibit 31.f

I, Mark F. McGettrick, certify that:

1. I have reviewed this report on Form 10-Q of Dominion Gas Holdings, LLC;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2016	/s/ Mark F. McGettrick
	Mark F. McGettrick Executive Vice President and Chief Financial Officer

EX-32.A

Exhibit 32.a

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned officers of Dominion Resources, Inc. (the “Company”), certify that:

1. the Quarterly Report on Form 10-Q for the quarter ended June 30, 2016 (the “Report”), of the Company to which this certification is an exhibit fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)).

2. the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of June 30, 2016, and for the period then ended.

 /s/ Thomas F. Farrell II

Thomas F. Farrell II
President and Chief Executive Officer
August 3, 2016

 /s/ Mark F. McGettrick

Mark F. McGettrick
Executive Vice President and
Chief Financial Officer
August 3, 2016

EX-32.B

Exhibit 32.b

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned officers of Virginia Electric and Power Company (the “Company”), certify that:

1. the Quarterly Report on Form 10-Q for the quarter ended June 30, 2016 (the “Report”), of the Company to which this certification is an exhibit fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)).

2. the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of June 30, 2016, and for the period then ended.

 /s/ Thomas F. Farrell II                                

Thomas F. Farrell II

Chief Executive Officer

August 3, 2016

 /s/ Mark F. McGettrick                                

Mark F. McGettrick

Executive Vice President and Chief Financial Officer

August 3, 2016

EX-32.C

Exhibit 32.c

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, each of the undersigned officers of Dominion Gas Holdings, LLC (the “Company”), certify that:

1. the Quarterly Report on Form 10-Q for the quarter ended June 30, 2016 (the “Report”), of the Company to which this certification is an exhibit fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934 (15 U.S.C. 78m(a) or 78o(d)).

2. the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company as of June 30, 2016, and for the period then ended.

 /s/ Thomas F. Farrell II                                

Thomas F. Farrell II

Chief Executive Officer

August 3, 2016

 /s/ Mark F. McGettrick                                

Mark F. McGettrick

Executive Vice President and Chief Financial Officer 

August 3, 2016

EX-99

Exhibit 99

DOMINION RESOURCES, INC.

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended June 30, 2016
(millions, except per share amounts)
Operating Revenue	$	11,046
Operating Expenses		7,621
Income from operations		3,425
Other income		205
Interest and related charges		925
Income from operations including noncontrolling interests before income tax expense		2,705
Income tax expense		747
Net income including noncontrolling interests		1,958
Noncontrolling interests		32
Net income Attributable to Dominion	$	1,926
Earnings Per Common Share – Basic
Income from operations	$	3.26
Noncontrolling interests		(0.05	)
Net income attributable to Dominion	$	3.21
Earnings Per Common Share – Diluted
Income from operations	$	3.25
Noncontrolling interests		(0.05	)
Net income attributable to Dominion	$	3.20

VIRGINIA ELECTRIC AND POWER COMPANY

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended June 30, 2016
(millions)
Operating Revenue	$	7,339
Operating Expenses		5,157
Income from operations		2,182
Other income		67
Interest and related charges		455
Income before income tax expense		1,794
Income tax expense		679
Net Income	$	1,115

DOMINION GAS HOLDINGS, LLC

CONDENSED CONSOLIDATED EARNINGS STATEMENT

(Unaudited)

	Twelve Months Ended June 30, 2016
(millions)
Operating Revenue	$	1,589
Operating Expenses		863
Income from operations		726
Other income		25
Interest and related charges		83
Income before income tax expense		668
Income tax expense		255
Net Income	$	413

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Jul. 15, 2016
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Trading Symbol	D
Entity Registrant Name	DOMINION RESOURCES INC /VA/
Entity Central Index Key	0000715957
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		625,763,030
Virginia Electric and Power Company
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Trading Symbol	VEL - PE
Entity Registrant Name	VIRGINIA ELECTRIC & POWER CO
Entity Central Index Key	0000103682
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		274,723
Dominion Gas Holdings, LLC
Entity Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Entity Registrant Name	Dominion Gas Holdings, LLC
Entity Central Index Key	0001603291
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0

XML

Consolidated Statements of Income - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Operating Revenue		$ 2,598	$ 2,747	$ 5,519	$ 6,156
Operating Expenses
Electric fuel and other energy-related purchases		551	591	1,185	1,544
Purchased electric capacity		45	90	113	184
Purchased gas		56	111	175	361
Other operations and maintenance		665	709	1,368	1,311
Depreciation, depletion and amortization		361	339	712	682
Other taxes		139	134	303	299
Total operating expenses		1,817	1,974	3,856	4,381
Income from operations		781	773	1,663	1,775
Other income		72	56	126	116
Interest and related charges		239	221	465	444
Income from operations including noncontrolling interests before income tax expense		614	608	1,324	1,447
Income tax expense		152	190	331	489
Net Income Including Noncontrolling Interests		462	418	993	958
Noncontrolling Interests		10	5	17	9
Net Income Attributable to Dominion		$ 452	$ 413	$ 976	$ 949
Earnings Per Common Share
Net income attributable to Dominion - Basic		$ 0.73	$ 0.70	$ 1.61	$ 1.61
Net income attributable to Dominion - Diluted		0.73	0.70	1.61	1.60
Dividends Declared Per Common Share (dollars per share)		$ 0.7000	$ 0.6475	$ 1.4000	$ 1.2950
Virginia Electric and Power Company
Operating Revenue	[1]	$ 1,776	$ 1,813	$ 3,666	$ 3,950
Operating Expenses
Electric fuel and other energy-related purchases	[1]	475	497	1,011	1,307
Purchased electric capacity		45	90	113	184
Affiliated suppliers		64	69	165	144
Other		322	376	671	697
Depreciation, depletion and amortization		247	231	495	469
Other taxes		70	69	144	143
Total operating expenses		1,223	1,332	2,599	2,944
Income from operations		553	481	1,067	1,006
Other income		18	21	34	36
Interest and related charges		113	108	227	216
Income from operations including noncontrolling interests before income tax expense		458	394	874	826
Income tax expense		178	148	331	311
Net Income Attributable to Dominion		280	246	543	515
Dominion Gas Holdings, LLC
Operating Revenue	[2]	368	395	799	926
Operating Expenses
Purchased gas	[2]	16	21	50	95
Other energy-related purchases		1	7	4	13
Affiliated suppliers		16	17	43	38
Other		58	107	155	160
Depreciation, depletion and amortization		52	53	95	104
Other taxes		39	37	91	92
Total operating expenses		182	242	438	502
Income from operations		186	153	361	424
Other income		9	4	15	13
Interest and related charges		23	18	45	35
Income from operations including noncontrolling interests before income tax expense		172	139	331	402
Income tax expense		67	54	128	156
Net Income Attributable to Dominion		$ 105	$ 85	$ 203	$ 246

[1] See Note 17 for amounts attributable to affiliates.

[2] See Note 17 for amounts attributable to related parties.

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net income including noncontrolling interests		$ 462	$ 418	$ 993	$ 958
Net income		452	413	976	949
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	[1]	(11)	92	42	34
Changes in unrealized net gains (losses) on investment securities	[2]	26	(11)	41	4
Changes in unrecognized pension and other postretirement benefit costs	[3]	0	3	0	3
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities	[4]	(44)	(61)	(107)	(2)
Net realized gains on investment securities	[5]	(8)	(12)	(10)	(33)
Net pension and other postretirement benefit costs	[6]	8	12	16	25
Changes in other comprehensive income (loss) from equity method investees	[7]	(1)	0	(1)	(1)
Total other comprehensive income (loss)		(30)	23	(19)	30
Comprehensive income including noncontrolling interests		432	441	974	988
Comprehensive income attributable to noncontrolling interests		10	5	17	9
Comprehensive income attributable to Dominion		422	436	957	979
Virginia Electric and Power Company
Net income		280	246	543	515
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	[8]	(6)	7	(15)	3
Changes in unrealized net gains (losses) on investment securities	[9]	3	0	6	1
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities	[10]	0	0	0	1
Net realized gains on investment securities	[11]	(1)	(2)	(1)	(3)
Total other comprehensive income (loss)		(4)	5	(10)	2
Comprehensive income attributable to Dominion		276	251	533	517
Dominion Gas Holdings, LLC
Net income		105	85	203	246
Other comprehensive income (loss), net of taxes:
Net deferred gains (losses) on derivatives-hedging activities	[12]	(9)	3	(15)	(1)
Amounts reclassified to net income:
Net derivative (gains) losses-hedging activities	[13]	0	(1)	(2)	(1)
Net pension and other postretirement benefit costs	[14]	1	1	1	2
Total other comprehensive income (loss)		(8)	3	(16)	0
Comprehensive income attributable to Dominion		$ 97	$ 88	$ 187	$ 246

[1] Net of $7 million and $(59) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(26) million and $(19) million tax for the six months ended June 30, 2016 and 2015, respectively.

[2] Net of $(15) million and $6 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(25) million and $(5) million tax for the six months ended June 30, 2016 and 2015, respectively.

[3] Net of $--- million and $3 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $--- million and $3 million tax for the six months ended June 30, 2016 and 2015, respectively.

[4] Net of $28 million and $41 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $67 million and $2 million tax for the six months ended June 30, 2016 and 2015, respectively.

[5] Net of $5 million and $8 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $6 million and $20 million tax for the six months ended June 30, 2016 and 2015, respectively.

[6] Net of $(6) million and $(9) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(12) million and $(18) million tax for the six months ended June 30, 2016 and 2015, respectively.

[7] Net of $--- million and $1 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $--- million and $1 million tax for the six months ended June 30, 2016 and 2015, respectively.

[8] Net of $4 million and $(4) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $9 million and $(2) million tax for the six months ended June 30, 2016 and 2015, respectively.

[9] Net of $(3) million and $1 million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(4) million and $--- million tax for the six months ended June 30, 2016 and 2015, respectively.

[10] Net of $--- million tax for both the three months ended June 30, 2016 and 2015, and net of $(1) million and $--- million tax for the six months ended June 30, 2016 and 2015, respectively.

[11] Net of $1 million tax for both the three months ended June 30, 2016 and 2015, and net of $1 million tax for both the six months ended June 30, 2016 and 2015.

[12] Net of $4 million and $(1) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $8 million and $1 million tax for the six months ended June 30, 2016 and 2015, respectively.

[13] Net of $(2) million and $--- million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $--- million tax for both the six months ended June 30, 2016 and 2015.

[14] Net of $--- million and $(1) million tax for the three months ended June 30, 2016 and 2015, respectively, and net of $(1) million and $(2) million tax for the six months ended June 30, 2016 and 2015, respectively.

XML

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net deferred gains (losses) on derivative-hedging activities, tax	$ 7	$ (59)	$ (26)	$ (19)
Changes in unrealized net gains (losses) on investment securities, tax	(15)	6	(25)	(5)
Changes in unrecognized pension and other postretirement benefit costs, tax	0	3	0	3
Net derivative (gains) losses-hedging activities, tax	28	41	67	2
Net realized gains on investment securities, tax	5	8	6	20
Net pension and other postretirement benefit costs, tax	(6)	(9)	(12)	(18)
Changes in other comprehensive income (loss) from equity method investees, tax	0	1	0	1
Virginia Electric and Power Company
Net deferred gains (losses) on derivative-hedging activities, tax	4	(4)	9	(2)
Changes in unrealized net gains (losses) on investment securities, tax	(3)	1	(4)	0
Net derivative (gains) losses-hedging activities, tax	0	0	(1)	0
Net realized gains on investment securities, tax	1	1	1	1
Dominion Gas Holdings, LLC
Net deferred gains (losses) on derivative-hedging activities, tax	4	(1)	8	1
Net derivative (gains) losses-hedging activities, tax	(2)	0	0	0
Net pension and other postretirement benefit costs, tax	$ 0	$ (1)	$ (1)	$ (2)

XML

Consolidated Balance Sheets - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents		$ 377	$ 607	[1]
Restricted cash and cash equivalents		516	17	[1]
Customer receivables (less allowance for doubtful accounts)		1,140	1,200	[1]
Other receivables (less allowance for doubtful accounts)		139	169	[1]
Inventories		1,351	1,348	[1]
Prepayments		143	198	[1]
Regulatory assets	[2]	221	351
Other		477	650	[1]
Total current assets		4,143	4,189	[1]
Investments
Nuclear decommissioning trust funds		4,331	4,183	[1]
Investment in equity method affiliates		1,372	1,320	[1]
Other		277	271	[1]
Total investments		5,980	5,774	[1]
Property, Plant and Equipment
Property, plant and equipment		60,490	57,776	[1]
Accumulated depreciation, depletion and amortization		(16,808)	(16,222)	[1]
Total property, plant and equipment, net		43,682	41,554	[1]
Deferred Charges and Other Assets
Goodwill		3,294	3,294	[1]
Pension and other postretirement benefit assets		1,017	943	[1]
Regulatory assets		2,150	1,865	[1]
Other		1,103	1,029	[1]
Total deferred charges and other assets		7,564	7,131	[1]
Total assets		61,369	58,648	[1]
Current Liabilities
Securities due within one year		1,348	1,825	[1]
Short-term debt		3,437	3,509	[1]
Accounts payable		589	726	[1]
Accrued interest, payroll and taxes		561	515	[1]
Regulatory liabilities	[3]	161	100
Other	[4]	1,331	1,544	[1]
Total current liabilities		7,266	8,119	[1]
Long-Term Debt
Long-term debt		21,406	20,048	[1]
Junior subordinated notes		2,399	1,340	[1]
Remarketable subordinated notes		982	2,080	[1]
Total long-term debt		24,787	23,468	[1]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		7,666	7,414	[1]
Asset retirement obligations		1,941	1,887	[1]
Regulatory liabilities		2,318	2,285	[1]
Other		1,939	1,873	[1]
Total deferred credits and other liabilities		13,864	13,459	[1]
Total liabilities		45,917	45,046	[1]
Commitments and Contingencies				[1]
Equity
Common stock - no par	[5]	8,160	6,680	[1]
Retained earnings		6,585	6,458	[1]
Accumulated other comprehensive loss		(493)	(474)	[1]
Total common shareholders' equity		14,252	12,664	[1]
Noncontrolling interests		1,200	938	[1]
Total equity		15,452	13,602	[1]
Total liabilities and equity		61,369	58,648	[1]
Virginia Electric and Power Company
Current Assets
Cash and cash equivalents		61	18	[6]
Customer receivables (less allowance for doubtful accounts)		837	822	[6]
Other receivables (less allowance for doubtful accounts)		79	109	[6]
Affiliated receivables		2	296	[6]
Inventories		860	873	[6]
Prepayments		73	38	[6]
Regulatory assets		193	326	[6]
Other	[7]	39	22	[6]
Total current assets		2,144	2,504	[6]
Investments
Nuclear decommissioning trust funds		2,030	1,945	[6]
Other		4	3	[6]
Total investments		2,034	1,948	[6]
Property, Plant and Equipment
Property, plant and equipment		38,734	37,639	[6]
Accumulated depreciation, depletion and amortization		(12,076)	(11,708)	[6]
Total property, plant and equipment, net		26,658	25,931	[6]
Deferred Charges and Other Assets
Regulatory assets		966	667	[6]
Other	[7]	591	515	[6]
Total deferred charges and other assets		1,557	1,182	[6]
Total assets		32,393	31,565	[6]
Current Liabilities
Securities due within one year		99	476	[6]
Short-term debt		1,423	1,656	[6]
Accounts payable		311	366	[6]
Accrued interest, payroll and taxes		229	190	[6]
Regulatory liabilities	[3]	112	35	[6]
Payables to affiliates		74	73	[6]
Affiliated current borrowings		0	376	[6]
Other	[7]	585	558	[6]
Total current liabilities		2,833	3,730	[6]
Long-Term Debt
Total long-term debt		9,562	8,892	[6]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		4,885	4,654	[6]
Asset retirement obligations		1,154	1,104	[6]
Regulatory liabilities		1,956	1,929	[6]
Other	[7]	829	615	[6]
Total deferred credits and other liabilities		8,824	8,302	[6]
Total liabilities		21,219	20,924	[6]
Commitments and Contingencies				[6]
Equity
Common stock - no par	[8]	5,738	5,738	[6]
Other paid-in capital		1,113	1,113	[6]
Retained earnings		4,293	3,750	[6]
Accumulated other comprehensive loss		30	40	[6]
Total common shareholders' equity		11,174	10,641	[6]
Total liabilities and equity		32,393	31,565	[6]
Dominion Gas Holdings, LLC
Current Assets
Cash and cash equivalents		226	13	[9]
Customer receivables (less allowance for doubtful accounts)	[10]	176	219	[9]
Other receivables (less allowance for doubtful accounts)	[10]	11	7	[9]
Affiliated receivables		6	98	[9]
Inventories		90	78	[9]
Prepayments		59	88	[9]
Regulatory assets	[2]	25	23
Other	[10]	56	63	[9]
Total current assets		624	566	[9]
Investments
Total investments		99	104	[9]
Property, Plant and Equipment
Property, plant and equipment		10,053	9,693	[9]
Accumulated depreciation, depletion and amortization		(2,766)	(2,690)	[9]
Total property, plant and equipment, net		7,287	7,003	[9]
Deferred Charges and Other Assets
Goodwill		542	542	[9]
Regulatory assets	[11]	451	449
Pension and other postretirement benefit assets	[10]	1,579	1,510	[9]
Other	[10]	604	583	[9]
Total deferred charges and other assets		2,725	2,635	[9]
Total assets		10,735	10,308	[9]
Current Liabilities
Securities due within one year		400	400	[9]
Short-term debt		238	391	[9]
Accounts payable		124	201	[9]
Accrued interest, payroll and taxes		155	183	[9]
Regulatory liabilities	[3]	43	55
Payables to affiliates		17	22	[9]
Affiliated current borrowings		0	95	[9]
Other	[10]	161	183	[9]
Total current liabilities		1,095	1,475	[9]
Long-Term Debt
Total long-term debt		3,541	2,869	[9]
Deferred Credits and Other Liabilities
Deferred income taxes and investment tax credits		2,331	2,214	[9]
Regulatory liabilities	[12]	213	201
Other	[10]	412	432	[9]
Total deferred credits and other liabilities		2,743	2,646	[9]
Total liabilities		7,379	6,990	[9]
Commitments and Contingencies				[9]
Equity
Membership interests		3,471	3,417	[9]
Accumulated other comprehensive loss	[10]	(115)	(99)	[9]
Total common shareholders' equity		3,356	3,318	[9]
Total liabilities and equity		$ 10,735	$ 10,308	[9]

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[2] Current regulatory assets are presented in other current assets in Dominion's and Dominion Gas' Consolidated Balance Sheets

[3] Current regulatory liabilities are presented in other current liabilities in the Companies' Consolidated Balance Sheets

[4] See Note 3 for amounts attributable to related parties.

[5] 1 billion shares authorized; 617 million shares and 596 million shares outstanding at June 30, 2016 and December 31, 2015, respectively.

[6] Virginia Power’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[7] See Note 17 for amounts attributable to affiliates.

[8] 500,000 shares authorized; 274,723 shares outstanding at June 30, 2016 and December 31, 2015.

[9] Dominion Gas’ Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[10] See Note 17 for amounts attributable to related parties.

[11] Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets

[12] Noncurrent regulatory liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Customer receivables, allowance for doubtful accounts		$ 19	$ 32	[1]
Other receivables, allowance for doubtful accounts		$ 3	$ 2	[1]
Common stock, shares authorized		1,000,000,000	1,000,000,000	[1]
Common stock, shares outstanding		617,000,000	596,000,000
Virginia Electric and Power Company
Customer receivables, allowance for doubtful accounts		$ 13	$ 27	[1]
Other receivables, allowance for doubtful accounts		$ 1	$ 1	[1]
Common stock, shares authorized		500,000	500,000	[1]
Common stock, shares outstanding		274,723	274,723	[1]
Dominion Gas Holdings, LLC
Customer receivables, allowance for doubtful accounts	[2]	$ 1	$ 1	[3]
Other receivables, allowance for doubtful accounts	[2]	$ 2	$ 2	[3]

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[2] See Note 17 for amounts attributable to related parties.

[3] Dominion Gas’ Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

XML

Consolidated Statement of Equity - USD ($) shares in Millions, $ in Millions	Total		Total Common Shareholders' Equity	Common Stock	Retained Earnings	Accumulated Other Comprehensive Loss	Noncontrolling Interests
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive loss, net of tax	$ 30
Other comprehensive loss, net of tax	23
Ending Balance (in shares) at Jun. 30, 2016				617
Ending balance at Jun. 30, 2016	15,452		$ 14,252	$ 8,160	$ 6,585	$ (493)	$ 1,200
Beginning Balance (in shares) at Dec. 31, 2015				596
Beginning balance at Dec. 31, 2015	13,602	[1]	12,664	$ 6,680	6,458	(474)	938
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income including noncontrolling interests	993		976		976		17
Contributions from SunEdison to Four Brothers and Three Cedars	162		0				162
Sale of interest in merchant solar projects	139		22	22			117
Purchase of Dominion Midstream common units	(13)		(2)	$ (2)			(11)
Issuance of common stock (in shares)				21
Issuance of common stock	1,458		1,458	$ 1,458
Stock awards (net of change in unearned compensation)	6		6	6
Dividends and distributions	(872)		(849)		(849)		(23)
Other comprehensive loss, net of tax	(19)		(19)			(19)
Other	(4)		(4)	$ (4)
Ending Balance (in shares) at Jun. 30, 2016				617
Ending balance at Jun. 30, 2016	15,452		14,252	$ 8,160	6,585	(493)	1,200
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Other comprehensive loss, net of tax	(30)
Ending Balance (in shares) at Jun. 30, 2016				617
Ending balance at Jun. 30, 2016	$ 15,452		$ 14,252	$ 8,160	$ 6,585	$ (493)	$ 1,200

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

XML

Consolidated Statements of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016		Jun. 30, 2015
Operating Activities
Net income including noncontrolling interests	$ 993		$ 958
Net income	976		949
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)	853		822
Deferred income taxes and investment tax credits	275		399
Gains on the sales of assets and equity method investment in Iroquois	(45)		(71)
Other adjustments	(27)		(18)
Changes in:
Accounts receivable	82		214
Inventories	(3)		47
Deferred fuel and purchased gas costs, net	114		28
Prepayments	55		47
Accounts payable	(92)		(173)
Accrued interest, payroll and taxes	46		(41)
Margin deposit assets and liabilities	(13)		186
Other operating assets and liabilities	(220)		(238)
Net cash provided by operating activities	2,018		2,160
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(3,160)		(2,370)
Acquisition of solar development projects	0		(230)
Acquisition of DCG	0		(497)
Proceeds from sales of securities	709		580
Purchases of securities	(752)		(553)
Restricted cash and cash equivalents	(500)		0
Proceeds from assignments of shale development rights	5		28
Other	(27)		(42)
Net cash used in investing activities	(3,725)		(3,084)
Financing Activities
Repayment of short-term debt, net	(72)		(153)
Repayment and repurchase of short-term notes	(600)		0
Issuance of long-term debt	1,930		1,200
Repayment and repurchase of long-term debt	(500)		(8)
Proceeds from sale of interest in merchant solar projects	117		0
Contributions from SunEdison to Four Brothers and Three Cedars	162		0
Issuance of common stock	1,458		647
Common dividend payments	(849)		(765)
Other	(169)		(44)
Net cash provided by financing activities	1,477		877
Decrease in cash and cash equivalents	(230)		(47)
Cash and cash equivalents at beginning of period	607	[1]	318
Cash and cash equivalents at end of period	377		271
Significant noncash investing and financing activities:
Accrued capital expenditures	257		319
Virginia Electric and Power Company
Operating Activities
Net income	543		515
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization (including nuclear fuel)	589		555
Deferred income taxes and investment tax credits	228		13
Other adjustments	(11)		(6)
Changes in:
Accounts receivable	7		40
Affiliated receivables and payables	295		1
Inventories	13		25
Deferred fuel and purchased gas costs, net	105		(9)
Prepayments	(35)		229
Accounts payable	(10)		(9)
Accrued interest, payroll and taxes	39		38
Other operating assets and liabilities	(61)		2
Net cash provided by operating activities	1,702		1,394
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(1,226)		(1,292)
Purchases of nuclear fuel	(78)		(67)
Proceeds from sales of securities	347		209
Purchases of securities	(373)		(222)
Other	(6)		(27)
Net cash used in investing activities	(1,336)		(1,399)
Financing Activities
Repayment of short-term debt, net	(233)		80
Repayment of affiliated current borrowings, net	(376)		(427)
Issuance of long-term debt	750		700
Repayment and repurchase of long-term debt	(457)		(6)
Distribution payments to parent	0		(270)
Other	(7)		(5)
Net cash provided by financing activities	(323)		72
Decrease in cash and cash equivalents	43		67
Cash and cash equivalents at beginning of period	18	[2]	15
Cash and cash equivalents at end of period	61		82
Significant noncash investing and financing activities:
Accrued capital expenditures	142		117
Dominion Gas Holdings, LLC
Operating Activities
Net income	203		246
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:
Depreciation and amortization	95		104
Deferred income taxes and investment tax credits	125		55
Gains on the sales of assets and equity method investment in Iroquois	(45)		(71)
Other adjustments	4		0
Changes in:
Accounts receivable	39		106
Affiliated receivables and payables	87		(15)
Deferred fuel and purchased gas costs, net	11		28
Prepayments	29		111
Accounts payable	(75)		(132)
Accrued interest, payroll and taxes	(28)		(54)
Other operating assets and liabilities	(120)		(85)
Net cash provided by operating activities	325		293
Investing Activities
Plant construction and other property additions (including nuclear fuel)	(393)		(292)
Proceeds from sale of equity method investment in Iroquois	7		0
Proceeds from assignments of shale development rights	5		28
Other	(5)		(6)
Net cash used in investing activities	(386)		(270)
Financing Activities
Repayment of short-term debt, net	(153)		360
Repayment of affiliated current borrowings, net	(95)		(216)
Issuance of long-term debt	680		0
Distribution payments to parent	(150)		(164)
Other	(8)		(1)
Net cash provided by financing activities	274		(21)
Decrease in cash and cash equivalents	213		2
Cash and cash equivalents at beginning of period	13	[3]	9
Cash and cash equivalents at end of period	226		11
Significant noncash investing and financing activities:
Accrued capital expenditures	$ 42		$ 37

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[2] Virginia Power’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[3] Dominion Gas’ Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

XML

Nature of Operations

6 Months Ended

Jun. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Operations

Nature of Operations

Dominion, headquartered in Richmond, Virginia, is one of the nation’s largest producers and transporters of energy. Dominion’s operations are conducted through various subsidiaries, including Virginia Power and Dominion Gas. Virginia Power is a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and northeastern North Carolina. Dominion 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. Dominion Gas' principal wholly-owned subsidiaries are DTI, East Ohio and Dominion Iroquois. In August 2016, DTI transferred its gathering and processing facilities to Dominion Gathering and Processing, Inc., a newly-formed wholly-owned subsidiary of Dominion Gas.

XML

Significant Accounting Policies

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Significant Accounting Policies

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, 2015.

In the Companies' opinion, the accompanying unaudited Consolidated Financial Statements contain all adjustments necessary to present fairly their financial position as of June 30, 2016, their results of operations for the three and six months ended June 30, 2016 and 2015, their cash flows for the six months ended June 30, 2016 and 2015 and Dominion's statement of equity for the six months ended June 30, 2016. 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. As of June 30, 2016, Dominion owns the general partner and 64.8% of the limited partner interests in Dominion Midstream. The public’s ownership interest in Dominion Midstream is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements. Also, as of June 30, 2016, Dominion owns 50% of the units in and consolidates Four Brothers and Three Cedars. SunEdison’s ownership interest in Four Brothers and Three Cedars, as well as Terra Nova Renewable Partners' 33% interest in certain Dominion merchant solar projects, is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements. See Note 3 for further information on transactions with SunEdison.

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' 2015 Consolidated Financial Statements and Notes have been reclassified to conform to the 2016 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows, except for the reclassification of debt issuance costs as discussed in Note 2 to the Companies' Annual Report on Form 10-K for the year ended December 31, 2015.

Amounts disclosed for Dominion are inclusive of Virginia Power and/or Dominion Gas, where applicable.

XML

Acquisitions and Dispositions

6 Months Ended

Jun. 30, 2016

Business Combinations, Discontinued Operations and Disposal Groups [Abstract]

Acquisitions and Dispositions

Acquisitions and Dispositions

Dominion

Proposed Acquisition of Questar

Pursuant to the terms of the Questar Combination announced in February 2016, upon closing, each share of Questar common stock issued and outstanding immediately prior to the closing will be converted automatically into the right to receive $25 in cash per share, or approximately $4.4 billion in total. In addition, Questar’s debt, which currently totals approximately $1.5 billion is expected to remain outstanding. Dominion entered into agreements with several of its lending banks pursuant to which they have unfunded financing commitments to provide a $3.9 billion acquisition facility. In connection with receipt of proceeds from Dominion’s issuance of common stock, the acquisition facility was reduced from $3.9 billion to $3.14 billion in April 2016. See Note 14 for more information. At June 30, 2016, $500 million of such proceeds are included in restricted cash and cash equivalents in Dominion's Consolidated Balance Sheets. Dominion intends to permanently finance the transaction in a manner that supports its existing credit ratings targets by issuing a combination of common stock, mandatory convertibles and debt at Dominion, and indirectly through the issuance of securities at Dominion Midstream, the proceeds of which will be applied to pay Dominion for certain assets of Questar, which are, subject to relevant approvals, expected to be contributed to Dominion Midstream.

The transaction requires approval of Questar’s shareholders and clearance from the Federal Trade Commission under the Hart-Scott-Rodino Act. In February 2016, the Federal Trade Commission granted antitrust approval of the Questar Combination under the Hart-Scott-Rodino Act. In March 2016, Questar and Dominion filed for review and approval, as required, from the Utah Public Service Commission and the Wyoming Public Service Commission, and provided information regarding the transaction to the Idaho Public Utilities Commission. In May 2016, Questar's shareholders voted to approve the Questar Combination. The Questar Combination contains certain termination rights for both Dominion and Questar, and provides that, upon termination of the Questar Combination under specified circumstances, Dominion would be required to pay a termination fee of $154 million to Questar and Questar would be required to pay Dominion a termination fee of $99 million. Subject to any remaining required regulatory approvals and meeting closing conditions, Dominion targets closing by the end of 2016.

Non-Wholly-Owned Merchant Solar Projects

Acquisitions of Four Brothers and Three Cedars

In June 2015, Dominion acquired 50% of the units in Four Brothers from SunEdison for $64 million of consideration, consisting of $2 million in cash and a $62 million payable. As of June 30, 2016, an $11 million payable is included in other current liabilities in Dominion's Consolidated Balance Sheets. Four Brothers' purpose is to develop and operate four solar projects located in Utah, which will produce and sell electricity and renewable energy credits. The projects are expected to cost approximately $730 million to construct, including the initial acquisition cost. Dominion is obligated to contribute $445 million of capital to fund the construction of the projects and has contributed $370 million through June 30, 2016. The facilities are expected to begin commercial operations by the end of the third quarter of 2016, with generating capacity of approximately 320 MW.

In September 2015, Dominion acquired 50% of the units in Three Cedars from SunEdison for $43 million of consideration, consisting of $6 million in cash and a $37 million payable. As of June 30, 2016, a $7 million payable is included in other current liabilities in Dominion’s Consolidated Balance Sheets. Three Cedars’ purpose is to develop and operate three solar projects located in Utah, which will produce and sell electricity and renewable energy credits. The projects are expected to cost approximately $425 million to construct. Dominion is obligated to contribute $276 million of capital to fund the construction of the projects and has contributed $223 million through June 30, 2016. The facilities are expected to begin commercial operations by the end of the third quarter of 2016, with generating capacity of approximately 210 MW.

Long-term power purchase, interconnection and operation and maintenance agreements have been executed for both Four Brothers and Three Cedars. Dominion expects to claim 99% of the federal investment tax credits on the projects.

Dominion owns 50% of the voting interests in Four Brothers and Three Cedars and has a controlling financial interest over the entities through its rights to control operations. The allocation of the $64 million purchase price for Four Brothers resulted in $89 million of property, plant and equipment and $25 million of noncontrolling interest. The allocation of the $43 million purchase price for Three Cedars resulted in $65 million of property, plant and equipment and $22 million of noncontrolling interest. The noncontrolling interest for each entity was measured at fair value using the discounted cash flow method, with the primary components of the valuation being future cash flows (both incoming and outgoing) and the discount rate. Dominion determined its discount rate based on the cost of capital a utility-scale investor would expect, as well as the cost of capital an individual project developer could achieve via a combination of non-recourse project financing and outside equity partners. The acquired assets of Four Brothers and Three Cedars are included in the Dominion Generation operating segment.

Dominion has assumed the majority of the agreements to provide administrative and support services in connection with construction of the projects, operations and maintenance of the facilities and technical management services of the solar facilities. Costs related to services to be provided under these agreements were immaterial for the six months ended June 30, 2016. Subsequent to Dominion’s acquisition of Four Brothers and Three Cedars through June 30, 2016, SunEdison made contributions to Four Brothers and Three Cedars of $265 million in aggregate, which are reflected as noncontrolling interests in Dominion's Consolidated Balance Sheets.

In April 2016, SunEdison filed for Chapter 11 bankruptcy; however, this is not expected to have a material adverse effect on Dominion, Four Brothers or Three Cedars.

Wholly-Owned Merchant Solar Projects

The following table presents significant completed acquisitions of wholly-owned merchant solar projects by Dominion in the second quarter of 2015. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for all of the projects. Dominion has claimed federal investment tax credits on the projects. These projects are included in the Dominion Generation operating segment.

Completed Acquisition Date	Seller	Number of Projects	Project Location	Project Name(s)	Initial Acquisition Cost (millions)(1)		Project Cost (millions)(2)		Date of Commercial Operations	MW Capacity
April 2015	EC&R NA Solar PV, LLC	1	California	Alamo	$	66	$	66	May 2015	20
April 2015	EDF Renewable Development, Inc.	3	California	Cottonwood(3)	106		106		May 2015	24
June 2015	EDF Renewable Development, Inc.	1	California	Catalina 2	68		68		July 2015	18

(1) The purchase price was primarily allocated to Property, Plant and Equipment.

(2) Includes acquisition cost.

(3) One of the projects, Marin Carport, began commercial operations in 2016.

Sale of Interest in Merchant Solar Projects

In September 2015, Dominion signed an agreement to sell a noncontrolling interest (consisting of 33% of the equity interests) in all of its then currently wholly-owned merchant solar projects, 24 solar projects totaling approximately 425 MW, to SunEdison, including projects discussed in the table above. In December 2015, the sale of interest in 15 of the solar projects closed for $184 million with the sale of interest in the remaining projects completed in January 2016 for $117 million. Upon closing, SunEdison sold its interest in these projects to Terra Nova Renewable Partners. Terra Nova Renewable Partners has a future option to buy all or a portion of Dominion’s remaining 67% ownership in the projects upon the occurrence of certain events, none of which had occurred as of June 30, 2016 nor are expected to occur in the remainder of 2016.

Acquisition of DCG

In January 2015, Dominion completed the acquisition of 100% of the equity interests of DCG from SCANA Corporation for $497 million in cash, as adjusted for working capital. DCG owns and operates nearly 1,500 miles of FERC-regulated interstate natural gas pipeline in South Carolina and southeastern Georgia. This acquisition supports Dominion’s natural gas expansion into the Southeast. The allocation of the purchase price resulted in $277 million of net property, plant and equipment, $250 million of goodwill, of which approximately $225 million is expected to be deductible for income tax purposes, and $38 million of regulatory liabilities. The goodwill reflects the value associated with enhancing Dominion's regulated gas position, economic value attributable to future expansion projects as well as increased opportunities for synergies. The acquired assets of DCG are included in the Dominion Energy operating segment.

On March 24, 2015, DCG converted to a limited liability company under the laws of South Carolina and changed its name from Carolina Gas Transmission Corporation to DCG. On April 1, 2015, Dominion contributed 100% of the issued and outstanding membership interests of DCG to Dominion Midstream in exchange for total consideration of $501 million, as adjusted for working capital. Total consideration to Dominion consisted of the issuance of a two-year, $301 million senior unsecured promissory note payable by Dominion Midstream at an annual interest rate of 0.6%, and 5,112,139 common units, valued at $200 million, representing limited partner interests in Dominion Midstream. The number of units was based on the volume weighted average trading price of Dominion Midstream's common units for the ten trading days prior to April 1, 2015, or $39.12 per unit. Since Dominion consolidates Dominion Midstream for financial reporting purposes, this transaction was eliminated upon consolidation and did not impact Dominion's financial position or cash flows.

Dominion Gas

Assignments of Shale Development Rights

In December 2013, Dominion Gas closed an agreement with a natural gas producer to convey over time approximately 79,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields. The agreement provided for payments to Dominion Gas, subject to customary adjustments, of up to approximately $200 million over a period of nine years, and an overriding royalty interest in gas produced from the acreage. In March 2015, Dominion Gas and the natural gas producer closed on an amendment to the agreement, which included the immediate conveyance of approximately 9,000 acres of Marcellus Shale development rights and a two year extension of the term of the original agreement. The conveyance of development rights resulted in the recognition of $43 million ($27 million after-tax) of previously deferred revenue to operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. In April 2016, Dominion Gas and the natural gas producer closed on an amendment to the agreement, which included the immediate conveyance of a 32% partial interest in the remaining approximately 70,000 acres. This conveyance resulted in the recognition of the remaining $35 million ($21 million after-tax) of previously deferred revenue to operations and maintenance expense in Dominion Gas’ Consolidated Statements of Income.

In March 2015, Dominion Gas conveyed to a natural gas producer approximately 11,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields and received proceeds of $27 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $27 million ($16 million after-tax) gain, included in other operations and maintenance expense in Dominion Gas' Consolidated Statements of Income.

In November 2014, Dominion Gas closed on 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 connection with that agreement, in January 2016, Dominion Gas conveyed approximately 2,000 acres of Marcellus Shale development rights and received proceeds of $5 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $5 million ($3 million after-tax) gain, included in other operations and maintenance expense in Dominion Gas' Consolidated Statements of Income. Also in connection with that agreement, in July 2016, Dominion Gas conveyed to a natural gas producer approximately 2,000 acres of Marcellus Shale development rights underneath one of its natural gas storage fields and received proceeds of $5 million and an overriding royalty interest in gas produced from the acreage. This transaction resulted in a $5 million ($3 million after-tax) gain.

XML

Operating Revenue

6 Months Ended

Jun. 30, 2016

Regulated and Unregulated Operating Revenue [Abstract]

Operating Revenue

Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Dominion
Electric sales:
Regulated	$	1,718	$	1,779	$	3,560	$	3,891
Nonregulated	335		351		724		757
Gas sales:
Regulated	26		31		91		147
Nonregulated	54		87		172		295
Gas transportation and storage	369		385		784		856
Other	96		114		188		210
Total operating revenue	$	2,598	$	2,747	$	5,519	$	6,156
Virginia Power
Regulated electric sales	$	1,718	$	1,779	$	3,560	$	3,891
Other	58		34		106		59
Total operating revenue	$	1,776	$	1,813	$	3,666	$	3,950
Dominion Gas
Gas sales:
Regulated	$	12	$	21	$	41	$	78
Nonregulated	6		1		7		4
Gas transportation and storage	301		321		652		733
NGL revenue	9		22		26		51
Other	40		30		73		60
Total operating revenue	$	368	$	395	$	799	$	926

XML

Income Taxes

6 Months Ended

Jun. 30, 2016

Income Tax Disclosure [Abstract]

Income Taxes

Income Taxes

For continuing operations, including noncontrolling interests, the statutory United States federal income tax rate reconciles to the Companies' effective income tax rate as follows:

	Dominion				Virginia Power				Dominion Gas
Six Months Ended June 30,	2016		2015		2016		2015		2016		2015
United States statutory rate	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.3		3.3		4.0		3.8		3.8		3.9
Investment tax credits	(9.9	)	(2.7	)	—		—		—		—
Production tax credits	(0.8	)	(0.8	)	(0.6	)	(0.5	)	—		—
State legislative change	(1.3	)	—		—		—		—		—
Other, net	(2.3	)	(1.0	)	(0.5	)	(0.7	)	(0.1	)	—
Effective tax rate	25.0	%	33.8	%	37.9	%	37.6	%	38.7	%	38.9	%

As of June 30, 2016, 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, 2015 for a discussion of these unrecognized tax benefits.

XML

Earnings Per Share

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Earnings Per Share

Earnings Per Share

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions, except EPS)
Net income attributable to Dominion	$	452	$	413	$	976	$	949
Average shares of common stock outstanding – Basic	615.6		591.5		606.1		589.7
Net effect of dilutive securities(1)	1.4		1.0		1.5		1.5
Average shares of common stock outstanding – Diluted	617.0		592.5		607.6		591.2
Earnings Per Common Share – Basic	$	0.73	$	0.70	$	1.61	$	1.61
Earnings Per Common Share – Diluted	$	0.73	$	0.70	$	1.61	$	1.60

(1) Dilutive securities consist primarily of the 2013 Equity Units. See Note 14 in this report and Note 17 to the Consolidated Financial Statements in the Companies' Annual Report on Form 10-K for the year ended December 31, 2015 for more information.

The 2014 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three and six months ended June 30, 2016 and 2015, as the dilutive stock price threshold was not met.

XML

Accumulated Other Comprehensive Income

6 Months Ended

Jun. 30, 2016

Equity [Abstract]

Accumulated Other Comprehensive Income

Accumulated Other Comprehensive Income

Dominion

The following table presents Dominion’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 Income (Loss) From Equity Method Investee			Total
(millions)
Three Months Ended June 30, 2016
Beginning balance	$	(186	)	$	517		$	(789	)	$	(5	)	$	(463	)
Other comprehensive income before reclassifications: gains (losses)	(11		)	26			—			(1		)	14
Amounts reclassified from AOCI(1): (gains) losses	(44		)	(8		)	8			—			(44		)
Net current-period other comprehensive income (loss)	(55		)	18			8			(1		)	(30		)
Ending balance	$	(241	)	$	535		$	(781	)	$	(6	)	$	(493	)
Three Months Ended June 30, 2015
Beginning balance	$	(177	)	$	542		$	(769	)	$	(5	)	$	(409	)
Other comprehensive income before reclassifications: gains (losses)	92			(11		)	3			—			84
Amounts reclassified from AOCI(1): (gains) losses	(61		)	(12		)	12			—			(61		)
Net current-period other comprehensive income (loss)	31			(23		)	15			—			23
Ending balance	$	(146	)	$	519		$	(754	)	$	(5	)	$	(386	)
Six Months Ended June 30, 2016
Beginning balance	$	(176	)	$	504		$	(797	)	$	(5	)	$	(474	)
Other comprehensive income before reclassifications: gains (losses)	42			41			—			(1		)	82
Amounts reclassified from AOCI(1): (gains) losses	(107		)	(10		)	16			—			(101		)
Net current-period other comprehensive income (loss)	(65		)	31			16			(1		)	(19		)
Ending balance	$	(241	)	$	535		$	(781	)	$	(6	)	$	(493	)
Six Months Ended June 30, 2015
Beginning balance	$	(178	)	$	548		$	(782	)	$	(4	)	$	(416	)
Other comprehensive income before reclassifications: gains (losses)	34			4			3			(1		)	40
Amounts reclassified from AOCI(1): (gains) losses	(2		)	(33		)	25			—			(10		)
Net current-period other comprehensive income (loss)	32			(29		)	28			(1		)	30
Ending balance	$	(146	)	$	519		$	(754	)	$	(5	)	$	(386	)

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

The following table presents Dominion’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, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(87	)	Operating revenue
	2			Purchased gas
	3			Electric fuel and other energy-related purchases
Interest rate contracts	8			Interest and related charges
Foreign currency contracts	2			Other income

	(72		)
Tax	28			Income tax expense
	$	(44	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(20	)	Other income
Impairment	7			Other income
	(13		)
Tax	5			Income tax expense
	$	(8	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(3	)	Other operations and maintenance
Actuarial (gains) losses	17			Other operations and maintenance
	14
Tax	(6		)	Income tax expense
	$	8
Three Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(107	)	Operating revenue
	2			Purchased gas
Interest rate contracts	3			Interest and related charges
	(102		)
Tax	41			Income tax expense
	$	(61	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(25	)	Other income
Impairment	5			Other income
	(20		)
Tax	8			Income tax expense
	$	(12	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(3	)	Other operations and maintenance
Actuarial (gains) losses	24			Other operations and maintenance
	21
Tax	(9		)	Income tax expense
	$	12
Six Months Ended June 30, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(201	)	Operating revenue
	8			Purchased gas
	6			Electric fuel and other energy-related purchases
Interest rate contracts	11			Interest and related charges
Foreign currency contracts	2			Other income
	(174		)

Tax	67			Income tax expense
	$	(107	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(30	)	Other income
Impairment	14			Other income
	(16		)
Tax	6			Income tax expense
	$	(10	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(7	)	Other operations and maintenance
Actuarial (gains) losses	35			Other operations and maintenance
	28
Tax	(12		)	Income tax expense
	$	16
Six Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(15	)	Operating revenue
	7			Purchased gas
	(1		)	Electric fuel and other energy-related purchases
Interest rate contracts	5			Interest and related charges
	(4		)
Tax	2			Income tax expense
	$	(2	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(64	)	Other income
Impairment	11			Other income
	(53		)
Tax	20			Income tax expense
	$	(33	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(6	)	Other operations and maintenance
Actuarial (gains) losses	49			Other operations and maintenance
	43
Tax	(18		)	Income tax expense
	$	25

Dominion Gas

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

	Deferred Gains and Losses on Derivatives-Hedging Activities			Unrecognized Pension and Other Postretirement Benefit Costs			Total
(millions)
Three Months Ended June 30, 2016
Beginning balance	$	(25	)	$	(82	)	$	(107	)
Other comprehensive income before reclassifications: losses	(9		)	—			(9		)
Amounts reclassified from AOCI(1): losses	—			1			1
Net current-period other comprehensive income (loss)	(9		)	1			(8		)
Ending balance	$	(34	)	$	(81	)	$	(115	)
Three Months Ended June 30, 2015
Beginning balance	$	(24	)	$	(65	)	$	(89	)
Other comprehensive income before reclassifications: gains	3			—			3
Amounts reclassified from AOCI(1): (gains) losses	(1		)	1			—
Net current-period other comprehensive income	2			1			3
Ending balance	$	(22	)	$	(64	)	$	(86	)
Six Months Ended June 30, 2016
Beginning balance	$	(17	)	$	(82	)	$	(99	)
Other comprehensive income before reclassifications: losses	(15		)	—			(15		)
Amounts reclassified from AOCI(1): (gains) losses	(2		)	1			(1		)
Net current-period other comprehensive income (loss)	(17		)	1			(16		)
Ending balance	$	(34	)	$	(81	)	$	(115	)
Six Months Ended June 30, 2015
Beginning balance	$	(20	)	$	(66	)	$	(86	)
Other comprehensive income before reclassifications: losses	(1		)	—			(1		)
Amounts reclassified from AOCI(1): (gains) losses	(1		)	2			1
Net current-period other comprehensive income (loss)	(2		)	2			—
Ending balance	$	(22	)	$	(64	)	$	(86	)

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

The following table presents Dominion 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, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Foreign currency contracts	$	2		Other income
	2
Tax	(2		)	Income tax expense
	$	—
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	1		Other operations and maintenance
	1
Tax	—			Income tax expense
	$	1
Three Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
	(1		)
Tax	—			Income tax expense
	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	2		Other operations and maintenance
	2
Tax	(1		)	Income tax expense
	$	1
Six Months Ended June 30, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(4	)	Operating revenue
Foreign currency contracts	2			Other income
	(2		)
Tax	—			Income tax expense
	$	(2	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	2		Other operations and maintenance
	2
Tax	(1		)	Income tax expense
	$	1
Six Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
	(1		)
Tax	—			Income tax expense
	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	4		Other operations and maintenance
	4
Tax	(2		)	Income tax expense
	$	2

XML

Fair Value Measurements

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

Fair Value Measurements

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, 2015. See Note 9 in this report for further information about the Companies' derivatives and hedge accounting activities.

Dominion and Dominion Gas apply fair value measurements to foreign currency swaps used to manage the foreign currency exchange rate risk related to interest and principal payments denominated in foreign currencies. These swaps are designated as cash flow hedges for accounting purposes and are categorized as Level 2.

The inputs and assumptions used in measuring the fair value for foreign currency swaps include the following:

• Foreign currency forward exchange rates

• Credit quality of counterparties and the Companies

• Notional value

• Credit enhancements

• Time value

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 and futures contracts. An option model is used to value Level 3 physical and financial options. The discounted cash flow model for forwards and futures calculates mark-to-market valuations based on forward market prices, original transaction prices, volumes, risk-free rate of return, and credit spreads. The 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, forward market prices, credit spreads 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's quantitative information about Level 3 fair value measurements at June 30, 2016. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads and price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average(1)
Assets
Physical and financial forwards and futures:
Natural gas(2)	$	123	Discounted cash flow	Market price (per Dth)	(3)	(2) - 7	—
				Credit spread	(4)	1% - 6%	3	%
FTRs	6		Discounted cash flow	Market price (per MWh)	(3)	(8) - 3	1
Physical and financial options:
Natural gas	8		Option model	Market price (per Dth)	(3)	2 - 7	4
				Price volatility	(5)	20% - 42%	25	%
Total assets	$	137
Liabilities
Physical and financial forwards and futures:
Natural gas(2)	$	5	Discounted cash flow	Market price (per Dth)	(3)	(1) - 4	3
FTRs	7		Discounted cash flow	Market price (per MWh)	(3)	(2) - 5	1
Physical and financial options:
Natural gas	1		Option model	Market price (per Dth)	(3)	2 - 4	3
				Price volatility	(5)	29% - 42%	36	%
Total liabilities	$	13

(1) Averages weighted by volume.

(2) Includes basis.

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

(4) Represents credit spreads unrepresented in published markets.

(5) Represents volatilities unrepresented in published markets.

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

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

Recurring Fair Value Measurements

Dominion

The following table presents Dominion’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, 2016
Assets
Derivatives:
Commodity	$	—	$	192	$	137	$	329
Interest rate	—		25		—		25
Investments(1):
Equity securities:
United States:
Large cap	2,617		—		—		2,617
Other	5		—		—		5
REIT	72		—		—		72
Non-United States:
Large cap	10		—		—		10
Fixed income:
Corporate debt instruments	—		498		—		498
United States Treasury securities and agency debentures	462		236		—		698
State and municipal	—		364		—		364
Other	—		112		—		112
Cash equivalents and other	5		—		—		5
Total assets	$	3,171	$	1,427	$	137	$	4,735
Liabilities
Derivatives:
Commodity	$	—	$	87	$	13	$	100
Interest rate	—		366		—		366
Foreign currency	—		7		—		7
Total liabilities	$	—	$	460	$	13	$	473
At December 31, 2015

Assets
Derivatives:
Commodity	$	1	$	249	$	114	$	364
Interest rate	—		24		—		24
Investments(1):
Equity securities:
United States:
Large cap	2,547		—		—		2,547
Other	5		—		—		5
REIT	63		—		—		63
Non-United States:
Large cap	10		—		—		10
Fixed income:
Corporate debt instruments	—		437		—		437
United States Treasury securities and agency debentures	458		201		—		659
State and municipal	—		376		—		376
Other	—		100		—		100
Cash equivalents and other	2		2		—		4
Total assets	$	3,086	$	1,389	$	114	$	4,589
Liabilities
Derivatives:
Commodity	$	—	$	141	$	19	$	160
Interest rate	—		183		—		183
Total liabilities	$	—	$	324	$	19	$	343

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Beginning balance	$	109		$	76		$	95		$	107
Total realized and unrealized gains (losses):
Included in earnings	(10		)	(5		)	(17		)	10
Included in other comprehensive income (loss)	—			(1		)	3			(12		)
Included in regulatory assets/liabilities	15			(5		)	32			(29		)
Settlements	10			6			18			(8		)
Transfers out of Level 3	—			—			(7		)	3
Ending balance	$	124		$	71		$	124		$	71

The following table presents Dominion's classification of gains and losses included in earnings in the Level 3 fair value category. 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 months ended June 30, 2016 and 2015.

	Operating Revenue		Electric Fuel and Other Energy-Related Purchases			Total
(millions)
Three Months Ended June 30, 2016
Total gains (losses) included in earnings	$	—	$	(10	)	$	(10	)
Three Months Ended June 30, 2015
Total gains (losses) included in earnings	$	—	$	(5	)	$	(5	)
Six Months Ended June 30, 2016
Total gains (losses) included in earnings	$	—	$	(17	)	$	(17	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date	—		—			—
Six Months Ended June 30, 2015
Total gains (losses) included in earnings	$	2	$	8		$	10
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date	1		(1		)	—

Virginia Power

The following table presents Virginia Power's quantitative information about Level 3 fair value measurements at June 30, 2016. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads and price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average(1)
Assets
Physical and financial forwards and futures:
Natural gas(2)	$	121	Discounted cash flow	Market price (per Dth)	(3)	(2) - 7	—
				Credit spread	(4)	1% - 6%	3	%
FTRs	6		Discounted cash flow	Market price (per MWh)	(3)	(8) - 3	1
Physical and financial options:
Natural gas	5		Option model	Market price (per Dth)	(3)	2 - 7	4
				Price volatility	(5)	20% - 33%	24	%
Total assets	$	132
Liabilities
Physical and financial forwards and futures:
FTRs	$	7	Discounted cash flow	Market price (per MWh)	(3)	(2) - 5	1
Total liabilities	$	7

(1) Averages weighted by volume.

(2) Includes basis.

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

(4) Represents credit spreads unrepresented in published markets.

(5) Represents volatilities unrepresented in published markets.

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

Significant Unobservable Inputs	Position	Change to Input	Impact on Fair Value Measurement
Market price	Buy	Increase (decrease)	Gain (loss)
Market price	Sell	Increase (decrease)	Loss (gain)
Credit spread	Asset	Increase (decrease)	Loss (gain)
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, 2016
Assets
Derivatives:
Commodity	$	—	$	31	$	132	$	163
Investments(1):
Equity securities:
United States large cap	1,137		—		—		1,137
REIT	72		—		—		72
Fixed income:
Corporate debt instruments	—		283		—		283
United States Treasury securities and agency debentures	166		111		—		277
State and municipal	—		159		—		159
Other	—		48		—		48
Total assets	$	1,375	$	632	$	132	$	2,139
Liabilities
Derivatives:
Commodity	$	—	$	10	$	7	$	17
Interest rate	—		257		—		257
Total liabilities	$	—	$	267	$	7	$	274
At December 31, 2015
Assets
Derivatives:
Commodity	$	—	$	13	$	101	$	114
Interest rate	—		13		—		13
Investments(1):
Equity securities:
United States large cap	1,100		—		—		1,100
REIT	63		—		—		63
Fixed income:
Corporate debt instruments	—		238		—		238
United States Treasury securities and agency debentures	180		79		—		259
State and municipal	—		175		—		175
Other	—		34		—		34
Total assets	$	1,343	$	552	$	101	$	1,996
Liabilities
Derivatives:
Commodity	$	—	$	19	$	8	$	27
Interest rate	—		59		—		59
Total liabilities	$	—	$	78	$	8	$	86

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

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 June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Beginning balance	$	110		$	78		$	93		$	102
Total realized and unrealized gains (losses):
Included in earnings	(9		)	(5		)	(17		)	8
Included in regulatory assets/liabilities	15			(5		)	32			(29		)
Settlements	9			5			17			(8		)
Ending balance	$	125		$	73		$	125		$	73

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, 2016 and 2015. 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, 2016 and 2015.

Dominion Gas

The following table presents Dominion 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, 2016
Assets
Commodity	$	—	$	3	$	—	$	3
Total Assets	$	—	$	3	$	—	$	3
Liabilities
Commodity	$	—	$	5	$	—	$	5
Foreign currency	—		7		—		7
Total liabilities	$	—	$	12	$	—	$	12
At December 31, 2015
Assets
Commodity	$	—	$	5	$	6	$	11
Total Assets	$	—	$	5	$	6	$	11
Liabilities
Interest rate	$	—	$	14	$	—	$	14
Total liabilities	$	—	$	14	$	—	$	14

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

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016			2015
(millions)
Beginning balance	$	—	$	—		$	6		$	2
Total realized and unrealized gains (losses):
Included in earnings	—		(1		)	—			1
Included in other comprehensive income (loss)	—		—			2			(12		)
Settlements	—		—			—			(1		)
Transfers out of Level 3	—		—			(8		)	9
Ending balance	$	—	$	(1	)	$	—		$	(1	)

The gains and losses included in earnings in the Level 3 fair value category were classified in operating revenue in Dominion Gas' Consolidated Statements of Income for the three and six months ended June 30, 2015. 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, 2016 and 2015.

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 cash equivalents, customer and other 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, 2016				December 31, 2015
	Carrying Amount		Estimated Fair Value(1)		Carrying Amount		Estimated Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	22,754	$	25,400	$	21,873	$	23,210
Junior subordinated notes(3)	2,399		2,310		1,340		1,192
Remarketable subordinated notes(3)	982		1,037		2,080		2,129
Virginia Power
Long-term debt, including securities due within one year(3)	$	9,661	$	11,329	$	9,368	$	10,400
Dominion Gas
Long-term debt, including securities due within one year(4)	$	3,941	$	4,116	$	3,269	$	3,299

(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 and/or premium, and foreign currency remeasurement adjustments. At June 30, 2016 and December 31, 2015, includes the valuation of certain fair value hedges associated with fixed rate debt of $21 million and $7 million, respectively.

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

(4) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount and/or premium, and foreign currency remeasurement adjustments.

XML

Derivatives and Hedge Accounting Activities

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives and Hedge Accounting Activities

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, 2015. 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'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. Dominion Gas' and Virginia Power's derivative contracts consist of over-the-counter transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a counterparty. 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.

Dominion

Balance Sheet Presentation

The tables below present Dominion's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:

	June 30, 2016						December 31, 2015
	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	$	231	$	—	$	231	$	217	$	—	$	217
Exchange	91		—		91		138		—		138
Interest rate contracts:
Over-the-counter	25		—		25		24		—		24
Total derivatives, subject to a master netting or similar arrangement	347		—		347		379		—		379
Total derivatives, not subject to a master netting or similar arrangement	7		—		7		9		—		9
Total	$	354	$	—	$	354	$	388	$	—	$	388

			June 30, 2016								December 31, 2015
			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	$	231	$	16	$	—	$	215	$	217	$	37	$	—	$	180
Exchange	91		63		—		28		138		82		—		56
Interest rate contracts:
Over-the-counter	25		15		—		10		24		22		—		2
Total	$	347	$	94	$	—	$	253	$	379	$	141	$	—	$	238

	June 30, 2016						December 31, 2015
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	32	$	—	$	32	$	70	$	—	$	70
Exchange	63		—		63		82		—		82
Interest rate contracts:
Over-the-counter	366		—		366		183		—		183
Foreign currency contracts:
Over-the-counter	7		—		7		—		—		—
Total derivatives, subject to a master netting or similar arrangement	468		—		468		335		—		335
Total derivatives, not subject to a master netting or similar arrangement	5		—		5		8		—		8
Total	$	473	$	—	$	473	$	343	$	—	$	343

			June 30, 2016								December 31, 2015
			Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Commodity contracts:
Over-the-counter	$	32	$	16	$	1	$	15	$	70	$	37	$	—	$	33
Exchange	63		63		—		—		82		82		—		—
Interest rate contracts:
Over-the-counter	366		15		—		351		183		22		—		161
Foreign currency contracts:
Over-the-counter	7		—		—		7		—		—		—		—
Total	$	468	$	94	$	1	$	373	$	335	$	141	$	—	$	194

Volumes

The following table presents the volume of Dominion’s derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)	125		38
Basis	190		580
Electricity (MWh):
Fixed price	11,749,639		1,978,640
FTRs	99,882,813		—
Liquids (Gal)(2)	59,807,554		—
Interest rate(3)	$	2,400,000,000	$	2,100,000,000
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, 2016 and 2015, 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 gains or losses attributable to changes in the time value of options and 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’s Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	10		$	9		22 months
Electricity	65			65			18 months
Other	(1		)	(1		)	9 months
Interest rate	(312		)	(23		)	381 months
Foreign currency	(3		)	(3		)	120 months
Total	$	(241	)	$	47

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’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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	67	$	121	$	188
Interest rate	4		—		4
Total current derivative assets(1)	71		121		192
Noncurrent Assets
Commodity	6		135		141
Interest rate	21		—		21
Total noncurrent derivative assets(2)	27		135		162
Total derivative assets	$	98	$	256	$	354
LIABILITIES
Current Liabilities
Commodity	$	27	$	61	$	88
Interest rate	178		—		178

Foreign currency	5		—		5
Total current derivative liabilities(3)	210		61		271
Noncurrent Liabilities
Commodity	5		7		12
Interest rate	188		—		188
Foreign currency	2		—		2
Total noncurrent derivative liabilities(4)	195		7		202
Total derivative liabilities	$	405	$	68	$	473
At December 31, 2015
ASSETS
Current Assets
Commodity	$	101	$	151	$	252
Interest rate	3		—		3
Total current derivative assets(1)	104		151		255
Noncurrent Assets
Commodity	3		109		112
Interest rate	21		—		21
Total noncurrent derivative assets(2)	24		109		133
Total derivative assets	$	128	$	260	$	388
LIABILITIES
Current Liabilities
Commodity	$	32	$	116	$	148
Interest rate	164		—		164
Total current derivative liabilities(3)	196		116		312
Noncurrent Liabilities
Commodity	—		12		12
Interest rate	19		—		19
Total noncurrent derivative liabilities(4)	19		12		31
Total derivative liabilities	$	215	$	128	$	343

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

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

(3) Current derivative liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.

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

The following tables present the gains and losses on Dominion'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, 2016
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	87
Purchased gas				(2		)
Electric fuel and other energy-related purchases				(3		)
Total commodity	$	12		$	82		$	—
Interest rate(3)	(23		)	(8		)	(108		)
Foreign currency(4)	(7		)	(2		)	—
Total	$	(18	)	$	72		$	(108	)
Three Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	107
Purchased gas				(2		)
Total commodity	$	94		$	105		$	—
Interest rate(3)	57			(3		)	(91		)
Total	$	151		$	102		$	(91	)
Six Months Ended June 30, 2016
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	201
Purchased gas				(8		)
Electric fuel and other energy-related purchases				(6		)
Total commodity	$	185		$	187		$	—
Interest rate(3)	(110		)	(11		)	(241		)
Foreign currency(4)	(7		)	(2		)	—
Total	$	68		$	174		$	(241	)
Six Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	15
Purchased gas				(7		)
Electric fuel and other energy-related purchases				1
Total commodity	$	54		$	9		$	3
Interest rate(3)	(1		)	(5		)	42
Total	$	53		$	4		$	45

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

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

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

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015			2016			2015
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	(8	)	$	15		$	(6	)	$	18
Purchased gas	8			(7		)	7			(9		)
Electric fuel and other energy-related purchases	(9		)	3			(31		)	9
Other operations and maintenance	1			—			—			—
Total	$	(8	)	$	11		$	(30	)	$	18

(1) Includes derivative activity amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Dominion’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, 2016						December 31, 2015
	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	$	127	$	—	$	127	$	101	$	—	$	101
Interest rate contracts:
Over-the-counter	—		—		—		13		—		13
Total derivatives, subject to a master netting or similar arrangement	127		—		127		114		—		114
Total derivatives, not subject to a master netting or similar arrangement	36		—		36		13		—		13
Total	$	163	$	—	$	163	$	127	$	—	$	127

			June 30, 2016								December 31, 2015
			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	$	127	$	7	$	—	$	120	$	101	$	3	$	—	$	98
Interest rate contracts:
Over-the-counter	—		—		—		—		13		10		—		3
Total	$	127	$	7	$	—	$	120	$	114	$	13	$	—	$	101

	June 30, 2016						December 31, 2015
	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	$	14	$	—	$	14	$	5	$	—	$	5
Interest rate contracts:
Over-the-counter	257		—		257		59		—		59
Total derivatives, subject to a master netting or similar arrangement	271		—		271		64		—		64
Total derivatives, not subject to a master netting or similar arrangement	3		—		3		22		—		22
Total	$	274	$	—	$	274	$	86	$	—	$	86

			June 30, 2016								December 31, 2015
			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	$	14	$	7	$	1	$	6	$	5	$	3	$	—	$	2
Interest rate contracts:
Over-the-counter	257		—		—		257		59		10		—		49
Total	$	271	$	7	$	1	$	263	$	64	$	13	$	—	$	51

Volumes

The following table presents the volume of Virginia Power’s derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)	42		16
Basis	67		538
Electricity (MWh):
FTRs	97,710,646		—
Interest rate	$	700,000,000	$	1,100,000,000

(1) Includes options.

Ineffectiveness and AOCI

For the three and six months ended June 30, 2016 and 2015, 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 Virginia Power’s Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(21	)	$	(1	)	381 months
Total	$	(21	)	$	(1	)

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 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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	—	$	34	$	34
Total current derivative assets(1)	—		34		34
Noncurrent Assets
Commodity	—		129		129
Total noncurrent derivative assets(2)	—		129		129
Total derivative assets	$	—	$	163	$	163
LIABILITIES
Current Liabilities
Commodity	$	—	$	12	$	12
Interest rate	69		—		69
Total current derivative liabilities(3)	69		12		81
Noncurrent Liabilities
Commodity	—		5		5
Interest rate	188		—		188
Total noncurrent derivatives liabilities (4)	188		5		193
Total derivative liabilities	$	257	$	17	$	274
At December 31, 2015
ASSETS
Current Assets
Commodity	$	—	$	18	$	18
Total current derivative assets(1)	—		18		18
Noncurrent Assets
Commodity	—		96		96
Interest rate	13		—		13
Total noncurrent derivative assets(2)	13		96		109
Total derivative assets	$	13	$	114	$	127
LIABILITIES
Current Liabilities
Commodity	$	—	$	23	$	23
Interest rate	57		—		57
Total current derivative liabilities(3)	57		23		80
Noncurrent Liabilities
Commodity	—		4		4
Interest rate	2		—		2
Total noncurrent derivative liabilities(4)	2		4		6
Total derivative liabilities	$	59	$	27	$	86

(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, 2016
Derivative type and location of gains (losses):
Interest rate(3)	$	(10	)	$	—		$	(108	)
Total	$	(10	)	$	—		$	(108	)
Three Months Ended June 30, 2015
Derivative type and location of gains (losses):
Interest rate(3)	$	11		$	—		$	91
Total	$	11		$	—		$	91
Six Months Ended June 30, 2016
Derivative type and location of gains (losses):
Interest rate(3)	$	(24	)	$	(1	)	$	(241	)
Total	$	(24	)	$	(1	)	$	(241	)
Six Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Total commodity	$	—		$	(1	)	$	3
Interest rate(3)	5			—			42
Total	$	5		$	(1	)	$	45

(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.

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015		2016			2015
(millions)
Derivative type and location of gains (losses):
Commodity(2)	$	(10	)	$	5	$	(30	)	$	12
Total	$	(10	)	$	5	$	(30	)	$	12

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

(2) Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.

Dominion Gas

Balance Sheet Presentation

The tables below present Dominion Gas' derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting.

	June 30, 2016						December 31, 2015
	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	$	3	$	—	$	3	$	11	$	—	$	11
Total derivatives, subject to a master netting or similar arrangement	$	3	$	—	$	3	$	11	$	—	$	11

			June 30, 2016								December 31, 2015
			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	$	3	$	3	$	—	$	—	$	11	$	—	$	—	$	11
Total	$	3	$	3	$	—	$	—	$	11	$	—	$	—	$	11

	June 30, 2016						December 31, 2015
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	5	$	—	$	5	$	—	$	—	$	—
Interest rate contracts:
Over-the-counter	—		—		—		14		—		14
Foreign currency contracts:
Over-the-counter	7		—		7		—		—		—
Total derivatives, subject to a master netting or similar arrangement	$	12	$	—	$	12	$	14	$	—	$	14

			June 30, 2016								December 31, 2015
			Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Commodity contracts
Over-the-counter	$	5	$	3	$	—	$	2	$	—	$	—	$	—	$	—
Interest rate contracts:
Over-the-counter	—		—		—		—		14		—		—		14
Foreign currency contracts:
Over-the-counter	7		—		—		7		—		—		—		—
Total	$	12	$	3	$	—	$	9	$	14	$	—	$	—	$	14

Volumes

The following table presents the volume of Dominion Gas' derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price	7		—
Basis	7		—
NGLs (Gal)	52,247,554		—
Foreign currency(1)	$	—	$	280,000,000

(1) Maturity is determined based on final settlement period. Euro equivalent volumes are €250,000,000.

Ineffectiveness and AOCI

For the three and six months ended June 30, 2016 and 2015, 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 Dominion Gas' Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
NGLs	$	(1	)	$	(1	)	9 months
Interest rate	(30		)	(4		)	342 months
Foreign currency	(3		)	(3		)	120 months
Total	$	(34	)	$	(8	)

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 rates.

Fair Value and Gains and Losses on Derivative Instruments

The following tables present the fair values of Dominion 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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	2	$	1	$	3
Total current derivative assets(1)	2		1		3
Total derivative assets	$	2	$	1	$	3
LIABILITIES
Current Liabilities
Commodity	$	4	$	1	$	5
Foreign currency	5		—		5
Total current derivative liabilities(3)	9		1		10
Noncurrent Liabilities
Foreign currency	2		—		2
Total noncurrent derivative liabilities(4)	2		—		2
Total derivative liabilities	$	11	$	1	$	12
At December 31, 2015
ASSETS
Current Assets
Commodity	$	10	$	—	$	10
Total current derivative assets(1)	10		—		10
Noncurrent Assets
Commodity	1		—		1
Total noncurrent derivatives assets(2)	1		—		1
Total derivative assets	$	11	$	—	$	11
LIABILITIES
Noncurrent Liabilities
Interest rate	$	14	$	—	$	14
Total noncurrent derivative liabilities(4)	14		—		14
Total derivative liabilities	$	14	$	—	$	14

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

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

(3) Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.

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

The following table presents the gains and losses on Dominion 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, 2016
Derivative Type and Location of Gains (Losses):
Commodity	$	(6	)	$	—
Foreign currency(3)	(7		)	(2		)
Total	$	(13	)	$	(2	)
Three Months Ended June 30, 2015
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	1
Total commodity	$	—		$	1
Interest rate(2)	4			—
Total	$	4		$	1
Six Months Ended June 30, 2016
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	4
Total commodity	$	(7	)	$	4
Interest rate(2)	(9		)	—
Foreign currency(3)	(7		)	(2		)
Total	$	(23	)	$	2
Six Months Ended June 30, 2015
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	1
Total commodity	$	(2	)	$	1
Total	$	(2	)	$	1

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

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

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

	Amount of Gain (Loss) Recognized in Income on Derivatives
	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015		2016			2015
(millions)
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue	$	(2	)	$	3	$	(2	)	$	4
Total	$	(2	)	$	3	$	(2	)	$	4

XML

Investments

6 Months Ended

Jun. 30, 2016

Investments, Debt and Equity Securities [Abstract]

Investments

Investments

Dominion

Equity and Debt Securities

Rabbi Trust Securities

Marketable equity and debt securities and cash equivalents held in Dominion’s rabbi trusts and classified as trading totaled $104 million and $100 million at June 30, 2016 and December 31, 2015, respectively.

Decommissioning Trust Securities

Dominion holds marketable equity and debt securities (classified as available-for-sale), cash equivalents and cost method investments in nuclear decommissioning trust funds to fund future decommissioning costs for its nuclear plants. Dominion’s decommissioning trust funds are summarized below:

	Amortized Cost			Total  Unrealized Gains(1)		Total  Unrealized Losses(1)				Fair Value
(millions)
At June 30, 2016
Marketable equity securities:
United States large cap	$	1,326		$	1,251	$	—			$	2,577
REIT	61			11		—				72
Marketable debt securities:
Corporate bonds	474			25		(1		)		498
United States Treasury securities and agency debentures	672			26		—				698
State and municipal	290			31		—				321
Other	108			—		—				108
Cost method investments	69			—		—				69
Cash equivalents and other(2)	(12		)	—		—				(12		)
Total	$	2,988		$	1,344	$	(1	)	(3)	$	4,331
At December 31, 2015
Marketable equity securities:
United States large cap	$	1,295		$	1,213	$	—			$	2,508
REIT	59			4		—				63
Marketable debt securities:
Corporate bonds	433			11		(7		)		437
United States Treasury securities and agency debentures	654			8		(4		)		658
State and municipal	312			22		—				334
Other	99			—		—				99
Cost method investments	70			—		—				70
Cash equivalents and other(2)	14			—		—				14
Total	$	2,936		$	1,258	$	(11	)	(3)	$	4,183

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

(2) Includes pending purchases of securities of $16 million and pending sales of securities of $12 million at June 30, 2016 and December 31, 2015, respectively.

(3) The fair value of securities in an unrealized loss position was $90 million and $592 million at June 30, 2016 and December 31, 2015, respectively.

The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2016 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	212
Due after one year through five years	458
Due after five years through ten years	390
Due after ten years	565
Total	$	1,625

Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Proceeds from sales	$	341	$	243	$	709	$	580
Realized gains(1)	37		44		62		100
Realized losses(1)	15		12		34		29

(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 for Dominion were not material for the three and six months ended June 30, 2016 and 2015.

Virginia Power

Virginia Power holds marketable equity and debt securities (classified as available-for-sale), 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(1)		Total  Unrealized Losses(1)				Fair Value
(millions)
At June 30, 2016
Marketable equity securities:
United States large cap	$	590		$	546	$	—			$	1,136
REIT	61			11		—				72
Marketable debt securities:
Corporate bonds	271			13		(1		)		283
United States Treasury securities and agency debentures	270			7		—				277
State and municipal	141			17		—				158
Other	48			—		—				48
Cost method investments	69			—		—				69
Cash equivalents and other(2)	(13		)	—		—				(13		)
Total	$	1,437		$	594	$	(1	)	(3)	$	2,030
At December 31, 2015
Marketable equity securities:
United States large cap	$	574		$	525	$	—			$	1,099
REIT	59			4		—				63
Marketable debt securities:
Corporate bonds	237			5		(4		)		238
United States Treasury securities and agency debentures	260			1		(2		)		259
State and municipal	162			13		(1		)		174
Other	34			—		—				34
Cost method investments	70			—		—				70
Cash equivalents and other(2)	8			—		—				8
Total	$	1,404		$	548	$	(7	)	(3)	$	1,945

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

(2) Includes pending purchases of securities of $13 million and pending sales of securities of $8 million at June 30, 2016 and December 31, 2015, respectively.

(3) The fair value of securities in an unrealized loss position was $66 million and $281 million at June 30, 2016 and December 31, 2015, respectively.

The fair value of Virginia Power’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2016 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	71
Due after one year through five years	207
Due after five years through ten years	218
Due after ten years	270
Total	$	766

Presented below is selected information regarding Virginia Power’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Proceeds from sales	$	154	$	76	$	347	$	209
Realized gains(1)	18		19		30		37
Realized losses(1)	7		4		17		15

(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 for Virginia Power were not material for the three and six months ended June 30, 2016 and 2015.

Equity Method Investments

Dominion Gas

Iroquois

Dominion Gas' equity earnings totaled $9 million and $12 million for the six months ended June 30, 2016 and 2015, respectively. Dominion Gas received distributions from this investment of $11 million and $12 million for the six months ended June 30, 2016 and 2015, respectively. At June 30, 2016 and December 31, 2015, the carrying amount of Dominion Gas' investment of $98 million and $102 million, respectively, exceeded its share of underlying equity in net assets by $8 million. The difference reflects equity method goodwill and is not being amortized. In May 2016, Dominion Gas sold 0.65% of the non-controlling partnership interest in Iroquois to TransCanada for approximately $7 million, which resulted in a $5 million ($3 million after-tax) gain.

XML

Regulatory Assets and Liabilities

6 Months Ended

Jun. 30, 2016

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

Regulatory Assets and Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2016		December 31, 2015
(millions)
Dominion
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	95	$	90
Deferred nuclear refueling outage costs(2)	61		75
Deferred cost of fuel used in electric generation(3)	5		111
Other	60		75
Regulatory assets-current(4)	221		351
Unrecognized pension and other postretirement benefit costs(5)	992		1,015
Derivatives(6)	351		110
Deferred rate adjustment clause costs(1)	342		295
PJM transmission rates(7)	192		192
Income taxes recoverable through future rates(8)	137		126

Other	136		127
Regulatory assets-non-current	2,150		1,865
Total regulatory assets	$	2,371	$	2,216
Regulatory liabilities:
Deferred cost of fuel used in electric generation(3)	$	89	$	—
PIPP(9)	25		46
Other	47		54
Regulatory liabilities-current(10)	161		100
Provision for future cost of removal and AROs(11)	1,148		1,120
Nuclear decommissioning trust(12)	852		804
Derivatives(6)	108		79
Deferred cost of fuel used in electric generation(3)	26		97
Other	184		185
Regulatory liabilities-non-current	2,318		2,285
Total regulatory liabilities	$	2,479	$	2,385
Virginia Power
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	72	$	80
Deferred nuclear refueling outage costs(2)	61		75
Deferred cost of fuel used in electric generation(3)	5		111
Other	55		60
Regulatory assets-current	193		326
Derivatives(6)	351		110
Deferred rate adjustment clause costs(1)	254		213
PJM transmission rates(7)	192		192
Income taxes recoverable through future rates(8)	106		97
Other	63		55
Regulatory assets-non-current	966		667
Total regulatory assets	$	1,159	$	993
Regulatory liabilities:
Deferred cost of fuel used in electric generation(3)	$	89	$	—
Other	23		35
Regulatory liabilities-current(10)	112		35
Provision for future cost of removal(11)	913		890
Nuclear decommissioning trust(12)	852		804
Derivatives(6)	108		79
Deferred cost of fuel used in electric generation(3)	26		97
Other	57		59
Regulatory liabilities-non-current	1,956		1,929
Total regulatory liabilities	$	2,068	$	1,964
Dominion Gas
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	23	$	10
Other	2		13
Regulatory assets-current(4)	25		23
Unrecognized pension and other postretirement benefit costs(5)	277		282

Deferred rate adjustment clause costs(1)	88		82
Income taxes recoverable through future rates(8)	20		20
Other	66		65
Regulatory assets-non-current(13)	451		449
Total regulatory assets	$	476	$	472
Regulatory liabilities:
PIPP(9)	$	25	$	46
Other	18		9
Regulatory liabilities-current(10)	43		55
Provision for future cost of removal and AROs(11)	174		170
Other	39		31
Regulatory liabilities-non-current(14)	213		201
Total regulatory liabilities	$	256	$	256

(1) Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 12 for more information.

(2) 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.

(3) Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power's generation operations. See Note 12 for more information.

(4) Current regulatory assets are presented in other current assets in Dominion's and Dominion Gas' Consolidated Balance Sheets.

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

(6) 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.

(7) Reflects amounts related to PJM transmission cost allocation matter. See Note 12 for more information.

(8) Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.

(9) 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.

(10) Current regulatory liabilities are presented in other current liabilities in the Companies' Consolidated Balance Sheets.

(11) 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.

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

(13) Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

(14) Noncurrent regulatory liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

At June 30, 2016, $293 million of Dominion's, $272 million of Virginia Power's and $18 million of Dominion Gas' regulatory assets represented past expenditures on which they do not currently earn a return. These expenditures are expected to be recovered within the next two years.

XML

Regulatory Matters

6 Months Ended

Jun. 30, 2016

Regulated Operations [Abstract]

Regulatory Matters

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’s merchant generators sell electricity in the PJM, MISO, CAISO and ISO-NE wholesale markets, and to wholesale purchasers in the states of Tennessee, Georgia, California and Utah, under Dominion’s market-based sales tariffs authorized by FERC. 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. While Virginia Power cannot predict the outcome of the hearing, 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 United States 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 United States 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. Under the terms of the settlement, Virginia Power would be required to pay approximately $200 million to PJM over the next 10 years. Although the settlement agreement has not been accepted by FERC, and the settlement is opposed by a small group of parties to the proceeding, Virginia Power believes it is probable it will be required to make payment as an outcome of the settlement. Accordingly, as of June 30, 2016, Virginia Power has recorded a contingent liability of $200 million in other deferred credits and other liabilities, which is offset by a $192 million regulatory asset for the amount that will be recovered through retail rates in Virginia. The remaining $8 million was recorded in other operations and maintenance expense in the Consolidated Statement of Income for the year ended December 31, 2015.

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, 2015 and Note 12 to the Consolidated Financial Statements in the Companies' Quarterly Report on Form 10-Q for the quarter ended March 31, 2016.

Regulation Act Legislation

In February 2016, certain industrial customers of APCo petitioned the Virginia Commission to issue a declaratory judgment that Virginia legislation enacted in 2015 keeping APCo's base rates unchanged until at least 2020 (and Virginia Power's base rates unchanged until at least 2022) is unconstitutional, and to require APCo to make biennial review filings in 2016 and 2018.  Virginia Power intervened to support the constitutionality of this legislation. In July 2016, the Virginia Commission held in a divided opinion that this legislation is constitutional, and the industrial customers appealed this order to the Supreme Court of Virginia. This appeal is pending.

2015 Biennial Review

In May 2016, the Supreme Court of Virginia denied the Attorney General’s unopposed motion to suspend briefing in the previously granted appeals from the Virginia Commission’s orders in Virginia Power’s 2015 biennial review case. The Supreme Court of Virginia later granted leave for the industrial customer appellants to withdraw their appeals, thus concluding this matter.

Virginia Fuel Expenses

In May 2016, the Virginia Commission ordered Virginia Power’s proposed fuel rate decrease to become effective July 1, 2016 on an interim basis. Virginia Power’s proposed fuel rate represents a fuel revenue decrease of $286 million when applied to projected kilowatt-hour sales for the period July 1, 2016 to June 30, 2017. This case is pending.

Solar Facility Projects

In October 2015, Virginia Power filed an application with the Virginia Commission for CPCNs to construct and operate the Scott Solar, Whitehouse, and Woodland solar facilities and related distribution-level interconnection facilities. Virginia Power also applied for approval of Rider US-2 to recover the costs of these projects, which would increase Dominion’s renewable generation by a combined 56 MW at an estimated cost of approximately $130 million, excluding financing costs. In June 2016, the Virginia Commission granted the requested CPCNs and approved a $4 million revenue requirement, subject to true-up on a cost of service basis using a 9.6% ROE for Rider US-2 for the rate year beginning September 1, 2016.

In August 2016, Virginia Power filed an application with the Virginia Commission for a CPCN to construct and operate the Oceana solar facility and related distribution interconnection facilities on land owned by the United States Navy. The facility would begin commercial operations in late 2017 and increase Dominion's renewable generation by approximately 18 MW at an estimated cost of approximately $40 million, excluding financing costs. The facility is the subject of a public-private partnership whereby the Commonwealth of Virginia, a non-jurisdictional customer, will compensate Virginia Power for the facility’s net electrical energy output. Virginia Power will retire renewable energy certificates on the Commonwealth's behalf in an amount equal to those generated by the facility. There is no rate adjustment clause associated with this CPCN filing, nor will any costs of the project be recovered from jurisdictional customers. This case is pending.

Rate Adjustment Clauses

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

• The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. In June 2016, Virginia Power proposed a $254 million revenue requirement for the rate year beginning April 1, 2017, which represents a $3 million increase over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider R in conjunction with Bear Garden. In June 2016, Virginia Power proposed a $75 million revenue requirement for the rate year beginning April 1, 2017, which represents a $1 million increase over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider W in conjunction with Warren County. In June 2016, Virginia Power proposed a $126 million revenue requirement for the rate year beginning April 1, 2017, which represents a $9 million increase 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 2016, Virginia Power proposed a $28 million revenue requirement for the rate year beginning April 1, 2017, which represents a $1 million decrease over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider GV in conjunction with Greensville County. In June 2016, Virginia Power proposed a $89 million revenue requirement for the rate year beginning April 1, 2017, which represents a $49 million increase over the previous year. This matter is pending.

• The Virginia Commission previously approved Rider BW in conjunction with Brunswick County. In June 2016, the Virginia Commission approved a $119 million revenue requirement for the rate year beginning September 1, 2016. It also established a 10.6% ROE for Rider BW effective September 1, 2016.

• The Virginia Commission previously approved Rider T1 concerning transmission rates. In May 2016, Virginia Power proposed a $639 million total revenue requirement for the rate year beginning September 1, 2016, which represents a $1 million increase over the revenues projected to be produced during the rate year under current rates. In July 2016, the Virginia Commission approved Virginia Power's proposed total revenue requirement.

North Anna

Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna nuclear power station. If Virginia Power decides to build a new unit, it must first receive a COL from the NRC, approval of the Virginia Commission and certain environmental permits and other approvals. The COL is expected in 2017. Virginia Power has not yet committed to building a new nuclear unit at North Anna nuclear power station.

The motions and petitions filed by BREDL prior to April 2015 were dismissed, and under a previous ruling of the NRC, the contested portion of the COL proceeding remains terminated. The NRC is required to conduct a hearing in all COL proceedings, and if a new contention is not admitted, the mandatory NRC hearing will be uncontested.

In April 2015, BREDL filed a new motion and petition challenging the NRC’s reliance on its rule generically assessing the environmental impacts of continued onsite storage of spent nuclear fuel in licensing proceedings. The BREDL filings were substantially the same as those filed in other COL proceedings in which final environmental impact statements were issued prior to promulgation of the continued storage rule, like North Anna 3. In June 2015, the NRC denied the April 2015 motion and petition.

In August 2015, BREDL filed a petition in the United States Court of Appeals for the District of Columbia Circuit seeking review of the NRC’s June 2015 decision, and Virginia Power intervened. This petition and nine similar petitions relating to other NRC licensing proceedings were held in abeyance pending the outcome of the ongoing judicial review of the NRC’s continued storage rule before the same court. In June 2016, in New York v. NRC, the court upheld the NRC’s continued storage rule. In July 2016, the petitioners in New York v. NRC petitioned for rehearing en banc on their challenge to the continued storage rule, and the court ordered that BREDL’s August 2015 petition pertaining to the application of this rule to North Anna 3, and the similar petitions relating to other NRC proceedings, continue to be held in abeyance until the court’s disposition of the rehearing petition.

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 July 2016, East Ohio’s annual update of the PIPP Rider was automatically approved by the Ohio Commission after a 45 day waiting period from the date of the filing. The revised rider rate reflects the recovery over the twelve-month period from July 2016 through June 2017 of projected deferred program costs of approximately $32 million from April 2016 through June 2017, net of a refund for over-recovery of accumulated arrearages of approximately $28 million as of March 31, 2016.

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 2016, East Ohio filed an application with the Ohio Commission requesting approval to increase its UEX Rider to reflect a refund of over-recovered accumulated bad debt expense of approximately $8 million as of March 31, 2016, and recovery of prospective net bad debt expense projected to total approximately $19 million for the twelve-month period from April 2016 to March 2017. This case is pending.

West Virginia Regulation

In May 2016, Hope filed a PREP application with the West Virginia Commission requesting approval of a projected capital investment for 2017 of $27 million as part of a total five-year projected capital investment of $152 million. The new PREP customer rates would be effective November 1, 2016. This case is pending.

Dominion Carolina Gas

In June 2016, DCG received FERC authorization to construct and operate the approximately $45 million Columbia to Eastover

Project facilities, which are expected to be placed into service in the fourth quarter of 2016.

XML

Variable Interest Entities

6 Months Ended

Jun. 30, 2016

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entities

Variable Interest Entities

The primary beneficiary of a VIE is required to consolidate the VIE and to disclose certain information about its significant variable interests in the VIE. The primary beneficiary of a VIE is the entity that has both: 1) the power to direct the activities that most significantly impact the entity's economic performance and 2) the obligation to absorb losses or receive benefits from the entity that could potentially be significant to the VIE.

Dominion

Dominion owns the general partner interest and 64.8% of the limited partnership interests in Dominion Midstream, which owns a preferred equity interest and the general partner interest in Cove Point. Additionally, Dominion owns the manager and 67% of the membership interest in certain merchant solar facilities, as discussed in Note 2. Dominion has concluded that these entities are VIEs due to the limited partners or members lacking the characteristics of a controlling financial interest. Dominion is the primary beneficiary of Dominion Midstream and the merchant solar facilities, and Dominion Midstream is the primary beneficiary of Cove Point, as they have the power to direct the activities that most significantly impact their economic performance as well as the obligation to absorb losses and benefits which could be significant to them.

Dominion has an initial 45% membership interest in Atlantic Coast Pipeline. See Note 9 to the Companies' Annual Report on Form 10-K for the year ended December 31, 2015 for more details regarding the nature of this entity. Dominion concluded that Atlantic Coast Pipeline is a VIE because it has insufficient equity to finance its activities without additional subordinated financial support. Dominion has concluded that it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance, as the power to direct is shared among multiple unrelated parties. Dominion is obligated to provide capital contributions based on its ownership percentage. Dominion's maximum exposure to loss is limited to its current and future investment.

Dominion and Virginia Power

Dominion and Virginia Power’s nuclear decommissioning trust funds and Dominion’s rabbi trusts hold investments in limited partnerships or similar type entities (see Note 10 for further details). Dominion and Virginia Power concluded that these partnership investments are VIEs due to the limited partners lacking the characteristics of a controlling financial interest. Dominion and Virginia Power have concluded neither is the primary beneficiary as they do not have the power to direct the activities that most significantly impact these VIEs’ economic performance. Dominion and Virginia Power are obligated to provide capital contributions to the partnerships as required by each partnership agreement based on their ownership percentages. Dominion and Virginia Power’s maximum exposure to loss is limited to their current and future investments.

Dominion and Dominion Gas

Dominion previously concluded that Iroquois was a VIE because a non-affiliated Iroquois equity holder had the ability during a limited period of time to transfer its ownership interests to another Iroquois equity holder or its affiliate. At the end of the first quarter of 2016, such right no longer existed and, as a result, Dominion concluded that Iroquois is no longer a VIE.

Virginia Power

Virginia Power had long-term power and capacity contracts with five non-utility generators; however, contracts with two of these generators expired in 2015, leaving three non-utility generators with an aggregate summer generation capacity of approximately 418 MW. These contracts contain certain variable pricing mechanisms in the form of partial fuel reimbursement that Virginia Power considers to be variable interests. After an evaluation of the information provided by these entities, Virginia Power was unable to determine whether they were VIEs. However, the information they provided, as well as Virginia Power's knowledge of generation facilities in Virginia, enabled Virginia Power to conclude that, if they were VIEs, it would not be the primary beneficiary. This conclusion reflects Virginia Power's determination that its variable interests do not convey the power to direct the most significant activities that impact the economic performance of the entities during the remaining terms of Virginia Power's contracts and for the years the entities are expected to operate after its contractual relationships expire. The contracts expire at various dates ranging from 2017 to 2021. Virginia Power is not subject to any risk of loss from these potential VIEs other than its remaining purchase commitments which totaled $357 million as of June 30, 2016. Virginia Power paid $37 million and $55 million for electric capacity and $5 million and $23 million for electric energy to these entities in the three months ended June 30, 2016 and 2015, respectively. Virginia Power paid $74 million and $108 million for electric capacity and $12 million and $60 million for electric energy to these entities in the six months ended June 30, 2016 and 2015, respectively.

Dominion Gas

DTI has been engaged to oversee the construction of, and to subsequently operate and maintain, the projects undertaken by Atlantic Coast Pipeline based on the overall direction and oversight of Atlantic Coast Pipeline's members. An affiliate of DTI holds a membership interest in Atlantic Coast Pipeline, therefore DTI is considered to have a variable interest in Atlantic Coast Pipeline. The members of Atlantic Coast Pipeline hold the power to direct the construction, operations and maintenance activities of the entity. DTI has concluded it is not the primary beneficiary of Atlantic Coast Pipeline as it does not have the power to direct the activities of Atlantic Coast Pipeline that most significantly impact its economic performance. DTI has no obligation to absorb any losses of the VIE. See Note 17 for information about associated related party receivable balances.

Virginia Power and Dominion Gas

Virginia Power and Dominion Gas purchased shared services from DRS, an affiliated VIE, of $74 million and $29 million for the three months ended June 30, 2016, $83 million and $30 million for the three months ended June 30, 2015, $188 million and $64 million for the six months ended June 30, 2016 and $166 million and $58 million for the six months ended June 30, 2015, respectively. Virginia Power and Dominion Gas determined that neither is the primary beneficiary of DRS as neither has both the power to direct the activities that most significantly impact its economic performance as well as the obligation to absorb losses and benefits which could be significant to it. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Virginia Power and Dominion Gas. Virginia Power and Dominion Gas have no obligation to absorb more than their allocated shares of DRS costs.

XML

Significant Financing Transactions

6 Months Ended

Jun. 30, 2016

Debt Disclosure [Abstract]

Significant Financing Transactions

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 utilizes cash and letters of credit to fund collateral requirements. Collateral requirements are impacted by commodity prices, hedging levels, Dominion’s credit ratings and the credit quality of its counterparties.

Dominion

At June 30, 2016, Dominion’s commercial paper and letters of credit outstanding, as well as its capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	5,000	$	3,437	$	—	$	1,563
Joint revolving credit facility(1)	500		—		52		448
Total	$	5,500	$	3,437	$	52	$	2,011

(1) In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities can be used 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.

Virginia Power

Virginia Power’s short-term financing is supported through its access as co-borrower to the two joint revolving credit facilities. These credit facilities 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, 2016, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Dominion Gas, were as follows:

	Facility Limit(1)		Outstanding Commercial Paper		Outstanding Letters of Credit
(millions)
Joint revolving credit facility(1)	$	5,000	$	1,423	$	—
Joint revolving credit facility(1)	500		—		—
Total	$	5,500	$	1,423	$	—

(1) The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Virginia Power was $2.0 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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 has a $120 million credit facility. In May 2016, the maturity date for this facility was extended from April 2019 to April 2020. As of June 30, 2016, this facility supports $119 million of certain variable rate tax-exempt financings of Virginia Power.

Dominion Gas

Dominion Gas’ short-term financing is supported by its access as co-borrower to the two joint revolving credit facilities. These credit facilities 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, 2016, Dominion Gas' share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Virginia Power were as follows:

	Facility Limit(1)		Outstanding Commercial Paper		Outstanding Letters of Credit
(millions)
Joint revolving credit facility(1)	$	1,000	$	238	$	—
Joint revolving credit facility(1)	500		—		—
Total	$	1,500	$	238	$	—

(1) A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Dominion Gas was $1.0 billion. If Dominion 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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.

Remarketable Subordinated Notes

In March 2016 and May 2016, Dominion successfully remarketed the $550 million 2013 Series A 1.07% RSNs due 2021 and the $550 million 2013 Series B 1.18% RSNs due 2019, respectively, pursuant to the terms of the related 2013 Equity Units.  In connection with the remarketings, the interest rate on the Series A and Series B junior subordinated notes was reset to 4.104% and 2.962%, respectively, payable on a semi-annual basis and Dominion ceased to have the ability to redeem the notes at its option or defer interest payments. At June 30, 2016, the securities are included in junior subordinated notes in Dominion's Consolidated Balance Sheets. Dominion did not receive any proceeds from the remarketings.  Remarketing proceeds belonged to the investors holding the related 2013 Equity Units and were temporarily used to purchase a portfolio of treasury securities. Upon maturity of each portfolio, the proceeds were applied on behalf of investors on the related stock purchase contract settlement date to pay the purchase price to Dominion for issuance of 8.5 million shares of its common stock on both April 1, 2016 and July 1, 2016. See Issuance of Common Stock below for a description of common stock issued by Dominion in April 2016 and July 2016 under the stock purchase contracts.

Enhanced Junior Subordinated Notes

In the first quarter of 2016, Dominion purchased and cancelled $38 million and $4 million of the June 2006 hybrids and the September 2006 hybrids, respectively.

In July 2016, Dominion launched a tender offer to purchase up to $200 million in aggregate of additional June 2006 hybrids and September 2006 hybrids, which expired on August 1, 2016. In connection with the tender offer, Dominion purchased and cancelled $125 million and $74 million of the June 2006 hybrids and the September 2006 hybrids, respectively. All purchases were conducted in compliance with the applicable replacement capital covenants. Also in July 2016, Dominion issued $800 million of 5.25% July 2016 hybrids. The proceeds were used for general corporate purposes, including to finance the tender offer. The July 2016 hybrids are listed on the New York Stock Exchange under the symbol DRUA.

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

Long-term Debt

In May 2016, Dominion Gas issued $150 million of private placement 3.8% Senior Notes that mature in 2031. In June 2016, Dominion Gas issued $250 million of private placement 2.875% Senior Notes that mature in 2023. Also in June 2016, Dominion Gas issued €250 million of private placement 1.45% Senior Notes that mature in 2026. The notes were recorded at $280 million at issuance and included in long-term debt in the Consolidated Balance Sheets at $278 million at June 30, 2016.

Issuance of Common Stock

Dominion maintains Dominion Direct® and a number of employee savings plans through which contributions may be invested in Dominion’s common stock. These shares may either be newly issued or purchased on the open market with proceeds contributed to these plans.

In December 2014, Dominion filed an SEC shelf registration for the sale of debt and equity securities including the ability to sell common stock through an at-the-market program. Also in December 2014, Dominion entered into four separate sales agency agreements to effect sales under the program and pursuant to which it may offer from time to time up to $500 million aggregate amount of its common stock. 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 and the sales agents and in conformance with applicable securities laws. Following issuances during the first and second quarters of 2015, Dominion has the ability to issue up to approximately $200 million of stock under the 2014 sales agency agreements; however, no additional issuances have occurred under these agreements in 2016.

In both April 2016 and July 2016, Dominion issued 8.5 million shares under the related stock purchase contract entered into as part of Dominion's 2013 Equity Units. Additionally, Dominion completed a market issuance of equity in April 2016 of 10.2 million shares and receipt of proceeds of $756 million through a registered underwritten public offering. In connection with receipt of these proceeds, the acquisition financing commitments for the Questar Combination were reduced from $3.9 billion to $3.14 billion in April 2016.

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

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 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 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 financial position, liquidity or results of operations of the Companies.

Environmental Matters

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

Air

CAA

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

MATS

In December 2011, the EPA issued MATS for coal- and oil-fired electric utility steam generating units. The rule establishes strict emission limits for mercury, particulate matter as a surrogate for toxic metals and hydrogen chloride as a surrogate for acid gases. The rule includes a limited use provision for oil-fired units with annual capacity factors under 8% that provides an exemption from emission limits, and allows compliance with operational work practice standards. Compliance was required by April 16, 2015, with certain limited exceptions. However, in June 2014, the VDEQ granted a one-year MATS compliance extension for two coal-fired units at Yorktown power station to defer planned retirements and allow for continued operation of the units to address reliability concerns while necessary electric transmission upgrades are being completed. These coal units will need to continue operating until at least April 2017 due to delays in transmission upgrades needed to maintain electric reliability, which based on assumptions about the timing for required agency actions and construction schedules are expected to be completed by no earlier than the second quarter of 2017. Therefore, in October 2015, Virginia Power submitted a request to the EPA for an additional one year compliance extension under an EPA Administrative Order. The order was signed by the EPA in April 2016 allowing the Yorktown power station units to operate for up to one additional year, as required to maintain reliable power availability while transmission upgrades are being made.

In June 2015, the United States Supreme Court issued a decision holding that the EPA failed to take cost into account when the agency first decided to regulate the emissions from coal- and oil-fired plants, and remanded the MATS rule back to the United States Court of Appeals for the District of Columbia Circuit. However, the Supreme Court did not vacate or stay the effective date and implementation of the MATS rule. In November 2015, in response to the Supreme Court decision, the EPA proposed a supplemental finding that consideration of cost does not alter the agency’s previous conclusion that it is appropriate and necessary to regulate coal- and oil-fired electric utility steam generating units under Section 112 of the CAA. In December 2015, the District of Columbia Court of Appeals issued an order remanding the MATS rulemaking proceeding back to the EPA without setting aside judgment, noting that EPA had represented it was on track to issue a final finding regarding its consideration of cost. In April 2016, the EPA issued a final supplemental finding that consideration of costs does not alter its conclusion regarding appropriateness and necessity for the regulation. These actions do not change Virginia Power’s plans to close coal units at Yorktown power station or the need to complete necessary electricity transmission upgrades by 2017. Since the MATS rule remains in effect and Dominion is complying with the requirements of the rule, Dominion does not expect any adverse impacts to its operations at this time.

CAIR

The EPA established CAIR with the intent to require significant reductions in SO₂ and NO_X emissions from electric generating facilities. In July 2008, the United States Court of Appeals for the District of Columbia Circuit issued a ruling vacating CAIR. In December 2008, the Court denied rehearing, but also issued a decision to remand CAIR to the EPA. In July 2011, the EPA issued a replacement rule for CAIR, called CSAPR, that required 28 states to reduce power plant emissions that cross state lines. CSAPR established new SO₂ and NO_X emissions cap and trade programs that were completely independent of the current ARP. Specifically, CSAPR required reductions in SO₂ and NO_X emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NO_X emissions caps, NO_X emissions caps during the ozone season (May 1 through September 30) and annual SO₂ emission caps with differing requirements for two groups of affected states.

CSAPR

Following numerous petitions by industry participants for review and a successful motion for stay, in October 2014, the United States Court of Appeals for the District of Columbia Circuit ordered that the EPA’s motion to lift the stay of CSAPR be granted. Further, the Court granted the EPA’s request to shift the CSAPR compliance deadlines by three years, so that Phase 1 emissions budgets (which would have gone into effect in 2012 and 2013) will apply in 2015 and 2016, and Phase 2 emissions budgets will apply in 2017 and beyond. CSAPR replaced CAIR beginning in January 2015. The cost to comply is not expected to be material to Dominion’s or Virginia Power’s Consolidated Financial Statements. Future outcomes of any additional litigation and/or any action to issue a revised rule, including the EPA’s recent proposal to reduce the ozone season NO_X emission budgets beginning in 2017, could affect the assessment regarding cost of compliance.

Ozone Standards

In October 2015, the EPA issued a final rule tightening the ozone standard, set in 2008, from 75-ppb to 70-ppb. The EPA is expected to complete attainment designations for a new standard by December 2017 and states will have until 2020 or 2021 to develop plans to address the new standard. To comply with the 2008 standard, in April 2016 Dominion submitted the NO_X Reasonable Available Control Technology analysis for Unit 5 at Possum Point power station. Until the states have developed implementation plans, the Companies are unable to predict whether or to what extent the new rules will ultimately require additional controls. However, if significant expenditures are required to implement additional controls, it could adversely affect the Companies’ results of operations and cash flows.

NO_x and VOC Emissions

In April 2014, the Pennsylvania Department of Environmental Protection issued proposed regulations to reduce NO_X and VOC emissions from combustion sources. The regulations were finalized in April 2016. To comply with the regulations, Dominion Gas anticipates 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 $25 million.

NSPS

In August 2012, the EPA issued the first 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 September 2015, the EPA issued a proposed NSPS (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. The proposed regulation was finalized in June 2016. All projects which commenced construction after September 2015 will be required to comply with this regulation. Dominion and Dominion Gas are implementing the final regulation. Dominion currently estimates the potential impacts on results of operations, financial condition and/or cash flows related to this matter to be immaterial. Dominion Gas is still evaluating whether potential impacts on results of operations, financial condition and/or cash flows related to this matter will be material.

Methane Emissions

In January 2015, as part of its Climate Action Plan, the EPA announced plans to reduce methane emissions from the oil and gas sector including natural gas processing and transmission sources. In July 2015, the EPA announced the next generation of its voluntary Natural Gas STAR program, the Natural Gas STAR Methane Challenge Program. The proposed 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, Dominion joined the EPA as a founding partner in this program for its distribution companies, East Ohio and Hope, and DTI.

In March 2016, as part of President Obama’s Climate Action Plan, the EPA began development of regulations for reducing methane emissions from existing sources in the oil and natural gas sectors. In June 2016, the EPA issued a draft Information Collection Request to collect information on existing sources upstream of distribution in this sector. The final Information Collection Request is expected in the fourth quarter of 2016. Depending on the results of this Information Collection Request effort, the EPA may propose new regulations on existing sources. Dominion and Dominion Gas cannot currently estimate the potential impacts on results of operations, financial condition and/or cash flows related to this matter.

Climate Change Legislation and Regulation

In October 2013, the United States Supreme Court granted petitions filed by several industry groups, states, and the United States Chamber of Commerce seeking review of the United States Court of Appeals for the District of Columbia Circuit's June 2012 decision upholding the EPA’s regulation of GHG emissions from stationary sources under the CAA's permitting programs. In June 2014, the United States Supreme Court ruled that the EPA lacked the authority under the CAA to require PSD or Title V permits for stationary sources based solely on GHG emissions. However, the Court upheld the EPA’s ability to require BACT for GHG for sources that are otherwise subject to PSD or Title V permitting for conventional pollutants. In July 2014, the EPA issued a memorandum specifying that it will no longer apply or enforce federal regulations or EPA-approved PSD state implementation plan provisions that require new and modified stationary sources to obtain a PSD permit when GHGs are the only pollutant that would be emitted at levels that exceed the permitting thresholds. In August 2015, the EPA published a final rule rescinding the requirement for all new and modified major sources to obtain permits based solely on their GHG emissions. In addition, the EPA stated that it will continue to use the existing thresholds to apply to sources that are otherwise subject to PSD for conventional pollutants until it completes a new rulemaking either justifying and upholding those thresholds or setting new ones. Some states have issued interim guidance that follows the EPA guidance. Due to uncertainty regarding what additional actions states may take to amend their existing regulations and what action the EPA ultimately takes to address the Court ruling under a new rulemaking, the Companies cannot predict the impact to their financial statements at this time. 

In July 2011, the EPA signed a final rule deferring the need for PSD and Title V permitting for CO₂ emissions for biomass projects. This rule temporarily deferred for a period of up to three years 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.  The deferral policy expired in July 2014. In July 2013, the United States Court of Appeals for the District of Columbia Circuit vacated this rule; however, a mandate making this decision effective has not been issued.  Virginia Power converted three coal-fired generating stations, Altavista, Hopewell and Southampton, to biomass during the CO₂ deferral period.  It is unclear how the court's decision or the EPA's final policy regarding the treatment of specific feedstock will affect biomass sources that were permitted during the deferral period; however, the expenditures to comply with any new requirements could be material to Dominion's and Virginia Power's financial statements.

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 and Virginia Power have14 and 11 facilities, respectively, that may be subject to the final regulations. Dominion anticipates that it will have to install impingement control technologies at many of these stations that have once-through cooling systems. Dominion 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'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 that may be subject to additional wastewater treatment requirements associated with the final rule. The expenditures to comply with these new requirements are expected to be material.

Solid and Hazardous Waste

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 United States 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 United States government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.

From time to time, Dominion, Virginia Power, or Dominion 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. Each party can be held jointly, severally and strictly liable for the cleanup costs. These parties can also bring contribution actions against each other and seek reimbursement from their insurance companies. As a result, Dominion, Virginia Power, or Dominion 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. Except as noted below, the Companies do not believe this will have a material effect on results of operations, financial condition and/or cash flows.

In September 2011, the EPA issued a UAO to Virginia Power and 22 other parties, ordering specific remedial action of certain areas at the Ward Transformer Superfund site located in Raleigh, North Carolina. Virginia Power does not believe it is a liable party under CERCLA based on its alleged connection to the site. In November 2011, Virginia Power and a number of other parties notified the EPA that they are declining to undertake the work set forth in the UAO.

The EPA may seek to enforce a UAO in court pursuant to its enforcement authority under CERCLA, and may seek recovery of its costs in undertaking removal or remedial action. If the court determines that a respondent failed to comply with the UAO without sufficient cause, the EPA may also seek civil penalties of up to $37,500 per day for the violation and punitive damages of up to three times the costs incurred by the EPA as a result of the party's failure to comply with the UAO. Virginia Power is currently unable to make an estimate of the potential financial statement impacts related to the Ward Transformer matter.

Dominion has determined that it is associated with 17 former manufactured gas plant sites, three of which pertain to Virginia Power and 12 of which pertain to Dominion 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 one of the former sites, Dominion is conducting a state-approved post closure groundwater monitoring program and an environmental land use restriction has been recorded. Another site has been accepted into a state-based voluntary remediation program. Virginia Power is currently evaluating the nature and extent of the contamination from this site as well as potential remedial options. Preliminary costs for options under evaluation for the site range from $1 million to $22 million. 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

Following the completion of the Appalachian Gateway project in 2012, DTI received multiple change order requests and other claims for additional payments from a pipeline contractor for the project. In July 2013, DTI filed a complaint in United States District Court for the Eastern District of Virginia for breach of contract as well as accounting and declaratory relief. The contractor filed a motion to dismiss, or in the alternative, a motion to transfer venue to Pennsylvania and/or West Virginia, where the pipelines were constructed. DTI filed an opposition to the contractor’s motion in August 2013. In November 2013, the court granted the contractor’s motion on the basis that DTI must first comply with the dispute resolution process. In July 2015, the contractor filed a complaint against DTI in United States District Court for the Western District of Pennsylvania. In August 2015, DTI filed a motion to dismiss, or in the alternative, a motion to transfer venue to Virginia. In March 2016, the Pennsylvania court granted the motion to dismiss and transferred the case to the United States District Court for the Eastern District of Virginia. In April 2016, the Virginia court issued an order staying the proceedings and ordering mediation. A mediation occurred in May 2016 but was unsuccessful. In July 2016, DTI filed a motion to dismiss. This case is pending. DTI has accrued a liability of $6 million for this matter. Dominion Gas cannot currently estimate additional financial statement impacts, but there could be a material impact to its financial condition and/or cash flows.

Ash Pond and Landfill Closure Costs

In September 2014, Virginia Power received a notice from the Southern Environmental Law Center on behalf of the Potomac Riverkeeper and Sierra Club alleging CWA violations at Possum Point power station. The notice alleges unpermitted discharges to surface water and groundwater from Possum Point power station’s historical and active ash storage facilities. A similar notice from the Southern Environmental Law Center on behalf of the Sierra Club was subsequently received related to Chesapeake power station. In December 2014, Virginia Power offered to close all of its coal ash ponds and landfills at Possum Point power station, Chesapeake and Bremo power stations as settlement of the potential litigation. While the issue is open to potential further negotiations, the Southern Environmental Law Center declined the offer as presented in January 2015 and, in March 2015, filed a lawsuit related to its claims of the alleged CWA violations at Chesapeake power station. Virginia Power filed a motion to dismiss in April 2015, which was denied in November 2015. A trial was held in June 2016. This case is pending. As a result of the December 2014 settlement offer, Virginia Power recognized a charge of $121 million in other operations and maintenance expense in its Consolidated Statements of Income in the Companies’ Annual Report on Form 10-K for the year ended December 31, 2014.

In April 2015, the EPA’s final rule regulating the management of CCRs stored in impoundments (ash ponds) and landfills was published in the Federal Register. The final rule regulates 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. The enactment of the final rule in April 2015 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 April 2016, the EPA announced a partial settlement with certain environmental and industry organizations that had challenged the final CCR rule in the United States Court of Appeals for the District of Columbia Circuit. As part of the settlement, certain exemptions included in the final rule for inactive ponds that closed by April 2018 will be removed, resulting in inactive ponds ultimately being subject to the same requirements as existing ponds. In June 2016, the court issued an order approving the settlement, which requires the EPA to modify provisions in the final CCR rule concerning inactive ponds. Virginia Power does not believe this change will substantially impact its closure plans for inactive ponds.

In 2015, Virginia Power recorded a $386 million ARO related to future ash pond and landfill closure costs. Recognition of the ARO also resulted in a $99 million incremental charge recorded in other operations and maintenance expense in its Consolidated Statement of Income, a $166 million increase in property, plant, and equipment associated with asset retirement costs, and a $121 million reduction in other noncurrent liabilities related to reversal of the contingent liability described above since the ARO obligation created by the final CCR rule represents similar activities. Virginia Power is in the process of obtaining the necessary permits to complete the work. In February and March 2016, respectively, two parties filed administrative appeals in the Circuit Court for the City of Richmond challenging certain provisions, relating to ash pond dewatering activities, of Possum Point power station’s wastewater discharge permit issued by the VDEQ in January 2016. One of those parties withdrew its appeal in June 2016. Virginia Power cannot predict the financial impact associated with the remaining appeal, but believes that it will not be material. The actual AROs related to the CCR rule may vary substantially from the estimates used to record the increased obligation in 2015.

Cove Point

Dominion is constructing the Liquefaction Project at the Cove Point facility, which would enable the facility to liquefy domestically-produced natural gas and export it as LNG. In September 2014, FERC issued an order granting authorization for Cove Point to construct, modify and operate the Liquefaction Project. In October 2014, several parties filed a motion with FERC to stay the order and requested rehearing. In May 2015, FERC denied the requests for stay and rehearing.

Two parties have separately filed petitions for review of the FERC order in the United States Court of Appeals for the District of Columbia Circuit, which petitions have been 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. Cove Point believes that on remand FERC will be able to justify its decision. 

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 United States nuclear operators, Dominion 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 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 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 and Virginia Power do not expect material financial impacts related to compliance with Tier 2 and Tier 3 recommendations.

Guarantees, Surety Bonds and Letters of Credit

Dominion

At June 30, 2016, Dominion had issued $73 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of June 30, 2016, Dominion’s exposure under these guarantees was $43 million, primarily related to certain reserve requirements associated with non-recourse financing.

Dominion also enters into guarantee arrangements on behalf of its consolidated subsidiaries, primarily to facilitate their commercial transactions with third parties. To the extent that a liability subject to a guarantee has been incurred by one of Dominion's consolidated subsidiaries, that liability is included in the Consolidated Financial Statements. Dominion 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 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, 2016, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	27	$	27
Commodity transactions(3)	2,074		864
Nuclear obligations(4)	189		81
Cove Point(5)	1,900		—
Solar(6)	1,514		244
Other(7)	420		28
Total	$	6,124	$	1,244

(1) Represents the estimated portion of the guarantee's stated limit that is utilized as of June 30, 2016 based upon prevailing economic conditions and fact patterns specific to each guarantee arrangement. For those guarantees related to obligations that are recorded as liabilities by Dominion's subsidiaries, the value includes the recorded amount.

(2) Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, Dominion would be obligated to repay such amounts.

(3) Guarantees related to commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and related commodities and services. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion would be obligated to satisfy such obligation. Dominion and its subsidiaries receive similar guarantees as collateral for credit extended to others. The value provided includes certain guarantees that do not have stated limits.

(4) Guarantees related to certain DEI subsidiaries' potential retrospective premiums that could be assessed if there is a nuclear incident under Dominion's nuclear insurance programs and guarantees for a DEI subsidiary's and Virginia Power's commitment to buy nuclear fuel. Excludes Dominion's agreement to provide up to $150 million and $60 million to two DEI subsidiaries to pay the operating expenses of Millstone nuclear power station (in the event of a prolonged outage) and Kewaunee nuclear power station, respectively, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee nuclear power station also provides for funds through the completion of decommissioning.

(5) Guarantees related to Cove Point, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.

(6) Includes guarantees to facilitate the development of solar projects including guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects. 

(7) Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of June 30, 2016, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $45 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.

Additionally, at June 30, 2016, Dominion had purchased $120 million of surety bonds, including $69 million at Virginia Power and $21 million at Dominion Gas, and authorized the issuance of letters of credit by financial institutions of $52 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.

XML

Credit Risk

6 Months Ended

Jun. 30, 2016

Risks and Uncertainties [Abstract]

Credit Risk

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, 2015.

At June 30, 2016, Dominion's credit exposure related to energy marketing and price risk management activities totaled $111 million. Of this amount, investment grade counterparties, including those internally rated, represented 88%. No single counterparty, whether investment grade or non-investment grade, exceeded $31 million of exposure.

Credit-Related Contingent Provisions

The majority of Dominion's derivative instruments contain credit-related contingent provisions. These provisions require Dominion 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, 2016 and December 31, 2015, Dominion would have been required to post an additional $4 million and $12 million, respectively, of 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 had not posted any collateral at June 30, 2016 or December 31, 2015 related to derivatives with credit-related contingent provisions that are in a liability position and not fully collateralized with cash. The collateral posted includes any amounts paid related to non-derivative contracts and derivatives elected under the normal purchases and normal sales exception, per contractual terms. 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 as of June 30, 2016 and December 31, 2015 was $13 million and $49 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power and Dominion Gas were not material as of June 30, 2016 and December 31, 2015. See Note 9 for further information about derivative instruments.

XML

Related-Party Transactions

6 Months Ended

Jun. 30, 2016

Related Party Transactions [Abstract]

Related-Party Transactions

Related-Party Transactions

Virginia Power and Dominion Gas engage in related-party transactions primarily with other Dominion subsidiaries (affiliates). Virginia Power's and Dominion 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 Gas are included in Dominion's consolidated federal income tax return. Dominion'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 physical forwards and options, to manage commodity price risks associated with purchases of natural gas. As of June 30, 2016, Virginia Power’s derivative assets and liabilities with affiliates were each $36 million and $3 million, respectively. As of December 31, 2015, Virginia Power’s derivative assets and liabilities with affiliates were $13 million and $22 million, respectively. See Note 9 for more information.

Virginia Power participates in certain Dominion benefit plans described in Note 18. In Virginia Power's Consolidated Balance

Sheets at June 30, 2016 and December 31, 2015, amounts due to Dominion associated with these benefit plans included in other deferred credits and other liabilities were $356 million and $316 million, respectively, and amounts due from Dominion at June 30, 2016 and December 31, 2015 included in other deferred charges and other assets were $98 million and $77 million, respectively.

DRS 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.

Presented below are Virginia Power's significant transactions with DRS and other affiliates:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Commodity purchases from affiliates	$	99	$	94	$	244	$	346
Services provided by affiliates(1)	102		107		242		217
Services provided to affiliates	7		5		12		10

(1) Includes capitalized expenditures of $38 million for both the three months ended June 30, 2016 and 2015, respectively, and $77 million and $73 million for the six months ended June 30, 2016 and 2015, respectively.

Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. Virginia Power had no short-term demand note borrowings from Dominion as of June 30, 2016. There were $376 million in short-term demand note borrowings from Dominion as of December 31, 2015. Virginia Power had no outstanding borrowings under the Dominion money pool for its nonregulated subsidiaries as of June 30, 2016 and December 31, 2015. Interest charges related to Virginia Power's borrowings from Dominion were immaterial for the three and six months ended June 30, 2016 and 2015.

There were no issuances of Virginia Power's common stock to Dominion for the three and six months ended June 30, 2016 and 2015.

Dominion Gas

Transactions with Related Parties

Dominion Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Gas provides transportation and storage services to affiliates. Dominion Gas also enters into certain other contracts with affiliates, which are presented separately from contracts involving commodities or services. As of June 30, 2016 and December 31, 2015, all of Dominion Gas' commodity derivatives were with affiliates. See Notes 7 and 9 for more information.

Dominion Gas participates in certain Dominion benefit plans as described in Note 18. In Dominion Gas' Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, amounts due from Dominion associated with these benefit plans included in noncurrent pension and other postretirement benefit assets were $674 million and $652 million, respectively, and amounts due to Dominion at June 30, 2016 and December 31, 2015 included in other deferred credits and other liabilities were immaterial.

DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to related parties, including technical services. The amounts recognized for these services were as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Purchases of natural gas and transportation and storage services from affiliates	$	2	$	2	$	5	$	4
Sales of natural gas and transportation and storage services to affiliates	18		17		35		35
Services provided by related parties(1)	33		34		72		68
Services provided to related parties (2)	33		25		60		45

(1) Includes capitalized expenditures of $14 million and $15 million for the three months ended June 30, 2016 and 2015, respectively, and $24 million for both the six months ended June 30, 2016 and 2015.

(2) Amounts primarily attributable to Atlantic Coast Pipeline.

The following table presents affiliated and related-party activity reflected in Dominion Gas' Consolidated Balance Sheets:

	June 30, 2016		December 31, 2015
(millions)
Other receivables(1)	$	8	$	7
Customer receivables from related parties	10		4
Imbalances receivable from affiliates(2)	3		1
Affiliated notes receivable(3)	16		14

(1) Represents amounts due from Atlantic Coast Pipeline, a related-party VIE.

(2) Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.

(3) Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

Dominion Gas' borrowings under the intercompany revolving credit agreement with Dominion were immaterial and $95 million as of June 30, 2016 and December 31, 2015, respectively. Interest charges related to Dominion Gas' total borrowings from Dominion were immaterial for the three and six months ended June 30, 2016 and 2015.

XML

Employee Benefit Plans

6 Months Ended

Jun. 30, 2016

Compensation and Retirement Disclosure [Abstract]

Employee Benefit Plans

Employee Benefit Plans

In the first quarter of 2016, the Companies announced an organizational design initiative that will reduce their total workforces during 2016. The goal of the organizational design initiative was to streamline leadership structure and push decision making lower while also improving efficiency.  During the six months ended June 30, 2016, Dominion recorded a $65 million ($40 million after-tax) charge, including $33 million ($20 million after-tax) at Virginia Power and $8 million ($5 million after-tax) at Dominion Gas, primarily reflected in other operations and maintenance expense in their Consolidated Statements of Income due to severance pay and other costs related to the organizational design initiative.  The terms of the severance under the organizational design initiative were consistent with the Companies’ existing severance plans.

Dominion

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

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
(millions)
Three Months Ended June 30,
Service cost	$	28		$	31		$	8		$	10
Interest cost	78			72			17			16
Expected return on plan assets	(139		)	(133		)	(30		)	(30		)
Amortization of prior service cost (credit)	1			1			(7		)	(6		)
Amortization of net actuarial loss	27			40			2			2
Net periodic benefit cost (credit)	$	(5	)	$	11		$	(10	)	$	(8	)
Six Months Ended June 30,
Service cost	$	57		$	63		$	16		$	20
Interest cost	155			144			34			33
Expected return on plan assets	(278		)	(266		)	(59		)	(59		)
Amortization of prior service cost (credit)	1			1			(14		)	(13		)
Amortization of net actuarial loss	55			80			3			3
Net periodic benefit cost (credit)	$	(10	)	$	22		$	(20	)	$	(16	)

Employer Contributions

During the six months ended June 30, 2016, Dominion made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion expects to contribute approximately $12 million to its other postretirement benefit plans through VEBAs during the remainder of 2016.

Dominion Gas

Dominion Gas participates in certain Dominion 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, 2015. See Note 17 for more information.

The components of Dominion Gas' provision for net periodic benefit credit for employees represented by collective bargaining units were as follows:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
(millions)
Three Months Ended June 30,
Service cost	$	4		$	4		$	2		$	1
Interest cost	7			7			4			4
Expected return on plan assets	(34		)	(32		)	(7		)	(6		)
Amortization of net actuarial loss	4			5			1			—
Net periodic benefit credit	$	(19	)	$	(16	)	$	—		$	(1	)
Six Months Ended June 30,
Service cost	$	7		$	7		$	3		$	3
Interest cost	15			14			7			7
Expected return on plan assets	(67		)	(63		)	(12		)	(12		)
Amortization of net actuarial loss	7			10			1			1
Net periodic benefit credit	$	(38	)	$	(32	)	$	(1	)	$	(1	)

Employer Contributions

During the six months ended June 30, 2016, Dominion Gas made no contributions to its defined benefit pension plans or other postretirement benefit plans. Dominion 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 2016.

XML

Operating Segments

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

Operating Segments

Operating Segments

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

Primary Operating Segment	Description of Operations	Dominion	Virginia Power	Dominion Gas
DVP	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
Dominion Generation	Regulated electric fleet	X	X
	Merchant electric fleet	X
Dominion Energy	Gas transmission and storage(1)	X		X
	Gas distribution and storage	X		X
	Gas gathering and processing	X		X
	LNG import and storage	X
	Nonregulated retail energy marketing(2)	X

(1) Includes remaining producer services activities for Dominion.

(2) As a result of Dominion's decision to realign its business units effective for 2015 year-end reporting, nonregulated retail energy marketing operations were moved from the Dominion Generation segment to the Dominion Energy segment.

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

Dominion

The Corporate and Other Segment of Dominion includes its corporate, service company and other functions (including unallocated debt) and the net impact of operations that are discontinued or sold. In addition, Corporate and Other includes specific items attributable to Dominion'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, 2016, Dominion reported an after-tax net expense of $37 million for specific items in the Corporate and Other segment, with $26 million of these net expenses attributable to its operating segments. In the six months ended June 30, 2015, Dominion reported an after-tax net expense of $64 million for specific items in the Corporate and Other segment, with $62 million of these net expenses attributable to its operating segments.

The net expense for specific items attributable to Dominion's operating segments in 2016 primarily related to the impact of the following item:

• A $59 million ($36 million after-tax) charge related to an organizational design initiative, attributable to:

• DVP ($5 million after-tax);

• Dominion Energy ($12 million after-tax); and

• Dominion Generation ($19 million after-tax).

The net expense for specific items in 2015 primarily related to the impact of the following items, all of which were attributable to Dominion Generation:

• An $85 million ($52 million after-tax) write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015;

• A $45 million ($28 million after-tax) charge related to incremental future ash pond and landfill closure costs at certain utility generation facilities due to the enactment of the final CCR rule in April 2015; and

• A $17 million ($10 million after-tax) billing adjustment related to PJM; partially offset by

• A $45 million ($28 million after-tax) net gain on investments held in nuclear decommissioning trust funds.

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

	DVP		Dominion Generation(1)		Dominion Energy(1)		Corporate and Other			Adjustments/Eliminations(1)			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Total revenue from external customers	$	512	$	1,564	$	391	$	3		$	128		$	2,598
Intersegment revenue	6		2		124		133			(265		)	—
Total operating revenue	518		1,566		515		136			(137		)	2,598
Net income attributable to Dominion	104		171		162		15			—			452
Three Months Ended June 30, 2015
Total revenue from external customers	$	500	$	1,652	$	463	$	4		$	128		$	2,747
Intersegment revenue	5		6		115		144			(270		)	—
Total operating revenue	505		1,658		578		148			(142		)	2,747
Net income (loss) attributable to Dominion	117		250		129		(83		)	—			413
Six Months Ended June 30, 2016
Total revenue from external customers	$	1,068	$	3,257	$	876	$	6		$	312		$	5,519
Intersegment revenue	11		5		302		325			(643		)	—
Total operating revenue	1,079		3,262		1,178		331			(331		)	5,519
Net income (loss) attributable to Dominion	224		416		348		(12		)	—			976
Six Months Ended June 30, 2015
Total revenue from external customers	$	1,064	$	3,641	$	999	$	(9	)	$	461		$	6,156
Intersegment revenue	10		9		425		286			(730		)	—
Total operating revenue	1,074		3,650		1,424		277			(269		)	6,156
Net income (loss) attributable to Dominion	257		512		356		(176		)	—			949

(1) 2015 amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.

Intersegment sales and transfers for Dominion 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, 2016, Virginia Power reported an after-tax net expense of $19 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segments. In the six months ended June 30, 2015, Virginia Power reported an after-tax net expense of $87 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 2016 primarily related to the impact of the following item:

• A $33 million ($20 million after-tax) charge related to an organizational design initiative, attributable to:

• DVP ($5 million after-tax); and

• Dominion Generation ($15 million after-tax).

The net expense for specific items in 2015 primarily related to the impact of the following items, all of which were attributable to Dominion Generation:

• An $85 million ($52 million after-tax) write-off of deferred fuel costs associated with Virginia legislation enacted in February 2015;

• A $45 million ($28 million after-tax) charge related to incremental future ash pond and landfill closure costs at certain utility generation facilities due to the enactment of the final CCR rule in April 2015; and

• A $15 million ($9 million after-tax) billing adjustment related to PJM.

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

	DVP		Dominion Generation		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Operating revenue	$	512	$	1,264	$	—		$	1,776
Net income	104		174		2			280
Three Months Ended June 30, 2015
Operating revenue	$	502	$	1,311	$	—		$	1,813
Net income (loss)	117		155		(26		)	246
Six Months Ended June 30, 2016
Operating revenue	$	1,069	$	2,597	$	—		$	3,666
Net income (loss)	222		340		(19		)	543
Six Months Ended June 30, 2015
Operating revenue	$	1,069	$	2,896	$	(15	)	$	3,950
Net income (loss)	257		345		(87		)	515

Dominion Gas

The Corporate and Other Segment of Dominion Gas primarily includes specific items attributable to Dominion 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 Gas as a result of Dominion's basis in the net assets contributed.

In the six months ended June 30, 2016, Dominion Gas reported an after-tax net expense of $2 million for specific items in the Corporate and Other segment, all of which was attributable to its operating segment. In the six months ended June 30, 2015, Dominion Gas reported no amounts for specific items in the Corporate and Other segment.

The net expense for specific items in 2016 primarily related to an $8 million ($5 million after-tax) charge related to an organizational design initiative.

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

	Dominion Energy		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Operating revenue	$	368	$	—		$	368
Net income (loss)	108		(3		)	105
Three Months Ended June 30, 2015
Operating revenue	$	395	$	—		$	395
Net income (loss)	87		(2		)	85
Six Months Ended June 30, 2016
Operating revenue	$	799	$	—		$	799
Net income (loss)	211		(8		)	203
Six Months Ended June 30, 2015
Operating revenue	$	926	$	—		$	926
Net income (loss)	251		(5		)	246

XML

Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Basis of Accounting

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, 2015.

Estimates

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.

Consolidation

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.

Consolidation, consolidated entities and noncontrolling interest

For certain partnership structures, income is allocated based on the liquidation value of the underlying contractual arrangements. As of June 30, 2016, Dominion owns the general partner and 64.8% of the limited partner interests in Dominion Midstream. The public’s ownership interest in Dominion Midstream is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements. Also, as of June 30, 2016, Dominion owns 50% of the units in and consolidates Four Brothers and Three Cedars. SunEdison’s ownership interest in Four Brothers and Three Cedars, as well as Terra Nova Renewable Partners' 33% interest in certain Dominion merchant solar projects, is reflected as noncontrolling interest in Dominion’s Consolidated Financial Statements.

Reclassifications

Certain amounts in the Companies' 2015 Consolidated Financial Statements and Notes have been reclassified to conform to the 2016 presentation for comparative purposes. The reclassifications did not affect the Companies’ net income, total assets, liabilities, equity or cash flows, except for the reclassification of debt issuance costs as discussed in Note 2 to the Companies' Annual Report on Form 10-K for the year ended December 31, 2015.

XML

Acquisitions and Dispositions (Tables)

6 Months Ended

Jun. 30, 2016

Business Combinations, Discontinued Operations and Disposal Groups [Abstract]

Schedule of Acquisitions of Solar Projects

The following table presents significant completed acquisitions of wholly-owned merchant solar projects by Dominion in the second quarter of 2015. Long-term power purchase, interconnection and operation and maintenance agreements have been executed for all of the projects. Dominion has claimed federal investment tax credits on the projects. These projects are included in the Dominion Generation operating segment.

Completed Acquisition Date	Seller	Number of Projects	Project Location	Project Name(s)	Initial Acquisition Cost (millions)(1)		Project Cost (millions)(2)		Date of Commercial Operations	MW Capacity
April 2015	EC&R NA Solar PV, LLC	1	California	Alamo	$	66	$	66	May 2015	20
April 2015	EDF Renewable Development, Inc.	3	California	Cottonwood(3)	106		106		May 2015	24
June 2015	EDF Renewable Development, Inc.	1	California	Catalina 2	68		68		July 2015	18

(1) The purchase price was primarily allocated to Property, Plant and Equipment.

(2) Includes acquisition cost.

(3) One of the projects, Marin Carport, began commercial operations in 2016.

XML

Operating Revenue (Tables)

6 Months Ended

Jun. 30, 2016

Regulated and Unregulated Operating Revenue [Abstract]

Operating Revenue

The Companies’ operating revenue consists of the following:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Dominion
Electric sales:
Regulated	$	1,718	$	1,779	$	3,560	$	3,891
Nonregulated	335		351		724		757
Gas sales:
Regulated	26		31		91		147
Nonregulated	54		87		172		295
Gas transportation and storage	369		385		784		856
Other	96		114		188		210
Total operating revenue	$	2,598	$	2,747	$	5,519	$	6,156
Virginia Power
Regulated electric sales	$	1,718	$	1,779	$	3,560	$	3,891
Other	58		34		106		59
Total operating revenue	$	1,776	$	1,813	$	3,666	$	3,950
Dominion Gas
Gas sales:
Regulated	$	12	$	21	$	41	$	78
Nonregulated	6		1		7		4
Gas transportation and storage	301		321		652		733
NGL revenue	9		22		26		51
Other	40		30		73		60
Total operating revenue	$	368	$	395	$	799	$	926

XML

Income Taxes (Tables)

6 Months Ended

Jun. 30, 2016

Income Tax Disclosure [Abstract]

Effective Income Tax

For continuing operations, including noncontrolling interests, the statutory United States federal income tax rate reconciles to the Companies' effective income tax rate as follows:

	Dominion				Virginia Power				Dominion Gas
Six Months Ended June 30,	2016		2015		2016		2015		2016		2015
United States statutory rate	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%	35.0	%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.3		3.3		4.0		3.8		3.8		3.9
Investment tax credits	(9.9	)	(2.7	)	—		—		—		—
Production tax credits	(0.8	)	(0.8	)	(0.6	)	(0.5	)	—		—
State legislative change	(1.3	)	—		—		—		—		—
Other, net	(2.3	)	(1.0	)	(0.5	)	(0.7	)	(0.1	)	—
Effective tax rate	25.0	%	33.8	%	37.9	%	37.6	%	38.7	%	38.9	%

XML

Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Earnings Per Share Computation

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions, except EPS)
Net income attributable to Dominion	$	452	$	413	$	976	$	949
Average shares of common stock outstanding – Basic	615.6		591.5		606.1		589.7
Net effect of dilutive securities(1)	1.4		1.0		1.5		1.5
Average shares of common stock outstanding – Diluted	617.0		592.5		607.6		591.2
Earnings Per Common Share – Basic	$	0.73	$	0.70	$	1.61	$	1.61
Earnings Per Common Share – Diluted	$	0.73	$	0.70	$	1.61	$	1.60

(1) Dilutive securities consist primarily of the 2013 Equity Units. See Note 14 in this report and Note 17 to the Consolidated Financial Statements in the Companies' Annual Report on Form 10-K for the year ended December 31, 2015 for more information.

XML

Accumulated Other Comprehensive Income (Tables)

6 Months Ended

Jun. 30, 2016

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

The following table presents Dominion’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 Income (Loss) From Equity Method Investee			Total
(millions)
Three Months Ended June 30, 2016
Beginning balance	$	(186	)	$	517		$	(789	)	$	(5	)	$	(463	)
Other comprehensive income before reclassifications: gains (losses)	(11		)	26			—			(1		)	14
Amounts reclassified from AOCI(1): (gains) losses	(44		)	(8		)	8			—			(44		)
Net current-period other comprehensive income (loss)	(55		)	18			8			(1		)	(30		)
Ending balance	$	(241	)	$	535		$	(781	)	$	(6	)	$	(493	)
Three Months Ended June 30, 2015
Beginning balance	$	(177	)	$	542		$	(769	)	$	(5	)	$	(409	)
Other comprehensive income before reclassifications: gains (losses)	92			(11		)	3			—			84
Amounts reclassified from AOCI(1): (gains) losses	(61		)	(12		)	12			—			(61		)
Net current-period other comprehensive income (loss)	31			(23		)	15			—			23
Ending balance	$	(146	)	$	519		$	(754	)	$	(5	)	$	(386	)
Six Months Ended June 30, 2016
Beginning balance	$	(176	)	$	504		$	(797	)	$	(5	)	$	(474	)
Other comprehensive income before reclassifications: gains (losses)	42			41			—			(1		)	82
Amounts reclassified from AOCI(1): (gains) losses	(107		)	(10		)	16			—			(101		)
Net current-period other comprehensive income (loss)	(65		)	31			16			(1		)	(19		)
Ending balance	$	(241	)	$	535		$	(781	)	$	(6	)	$	(493	)
Six Months Ended June 30, 2015
Beginning balance	$	(178	)	$	548		$	(782	)	$	(4	)	$	(416	)
Other comprehensive income before reclassifications: gains (losses)	34			4			3			(1		)	40
Amounts reclassified from AOCI(1): (gains) losses	(2		)	(33		)	25			—			(10		)
Net current-period other comprehensive income (loss)	32			(29		)	28			(1		)	30
Ending balance	$	(146	)	$	519		$	(754	)	$	(5	)	$	(386	)

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

Reclassification out of Accumulated Other Comprehensive Income

The following table presents Dominion’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, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(87	)	Operating revenue
	2			Purchased gas
	3			Electric fuel and other energy-related purchases
Interest rate contracts	8			Interest and related charges
Foreign currency contracts	2			Other income

	(72		)
Tax	28			Income tax expense
	$	(44	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(20	)	Other income
Impairment	7			Other income
	(13		)
Tax	5			Income tax expense
	$	(8	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(3	)	Other operations and maintenance
Actuarial (gains) losses	17			Other operations and maintenance
	14
Tax	(6		)	Income tax expense
	$	8
Three Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(107	)	Operating revenue
	2			Purchased gas
Interest rate contracts	3			Interest and related charges
	(102		)
Tax	41			Income tax expense
	$	(61	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(25	)	Other income
Impairment	5			Other income
	(20		)
Tax	8			Income tax expense
	$	(12	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(3	)	Other operations and maintenance
Actuarial (gains) losses	24			Other operations and maintenance
	21
Tax	(9		)	Income tax expense
	$	12
Six Months Ended June 30, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(201	)	Operating revenue
	8			Purchased gas
	6			Electric fuel and other energy-related purchases
Interest rate contracts	11			Interest and related charges
Foreign currency contracts	2			Other income
	(174		)

Tax	67			Income tax expense
	$	(107	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(30	)	Other income
Impairment	14			Other income
	(16		)
Tax	6			Income tax expense
	$	(10	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(7	)	Other operations and maintenance
Actuarial (gains) losses	35			Other operations and maintenance
	28
Tax	(12		)	Income tax expense
	$	16
Six Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(15	)	Operating revenue
	7			Purchased gas
	(1		)	Electric fuel and other energy-related purchases
Interest rate contracts	5			Interest and related charges
	(4		)
Tax	2			Income tax expense
	$	(2	)
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(64	)	Other income
Impairment	11			Other income
	(53		)
Tax	20			Income tax expense
	$	(33	)
Unrecognized pension and other postretirement benefit costs:
Prior service (credit) costs	$	(6	)	Other operations and maintenance
Actuarial (gains) losses	49			Other operations and maintenance
	43
Tax	(18		)	Income tax expense
	$	25

Dominion Gas Holdings, LLC

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

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

	Deferred Gains and Losses on Derivatives-Hedging Activities			Unrecognized Pension and Other Postretirement Benefit Costs			Total
(millions)
Three Months Ended June 30, 2016
Beginning balance	$	(25	)	$	(82	)	$	(107	)
Other comprehensive income before reclassifications: losses	(9		)	—			(9		)
Amounts reclassified from AOCI(1): losses	—			1			1
Net current-period other comprehensive income (loss)	(9		)	1			(8		)
Ending balance	$	(34	)	$	(81	)	$	(115	)
Three Months Ended June 30, 2015
Beginning balance	$	(24	)	$	(65	)	$	(89	)
Other comprehensive income before reclassifications: gains	3			—			3
Amounts reclassified from AOCI(1): (gains) losses	(1		)	1			—
Net current-period other comprehensive income	2			1			3
Ending balance	$	(22	)	$	(64	)	$	(86	)
Six Months Ended June 30, 2016
Beginning balance	$	(17	)	$	(82	)	$	(99	)
Other comprehensive income before reclassifications: losses	(15		)	—			(15		)
Amounts reclassified from AOCI(1): (gains) losses	(2		)	1			(1		)
Net current-period other comprehensive income (loss)	(17		)	1			(16		)
Ending balance	$	(34	)	$	(81	)	$	(115	)
Six Months Ended June 30, 2015
Beginning balance	$	(20	)	$	(66	)	$	(86	)
Other comprehensive income before reclassifications: losses	(1		)	—			(1		)
Amounts reclassified from AOCI(1): (gains) losses	(1		)	2			1
Net current-period other comprehensive income (loss)	(2		)	2			—
Ending balance	$	(22	)	$	(64	)	$	(86	)

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

Reclassification out of Accumulated Other Comprehensive Income

The following table presents Dominion 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, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Foreign currency contracts	$	2		Other income
	2
Tax	(2		)	Income tax expense
	$	—
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	1		Other operations and maintenance
	1
Tax	—			Income tax expense
	$	1
Three Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
	(1		)
Tax	—			Income tax expense
	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	2		Other operations and maintenance
	2
Tax	(1		)	Income tax expense
	$	1
Six Months Ended June 30, 2016
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(4	)	Operating revenue
Foreign currency contracts	2			Other income
	(2		)
Tax	—			Income tax expense
	$	(2	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	2		Other operations and maintenance
	2
Tax	(1		)	Income tax expense
	$	1
Six Months Ended June 30, 2015
Deferred (gains) and losses on derivatives-hedging activities:
Commodity contracts	$	(1	)	Operating revenue
	(1		)
Tax	—			Income tax expense
	$	(1	)
Unrecognized pension and other postretirement benefit costs:
Actuarial (gains) losses	$	4		Other operations and maintenance
	4
Tax	(2		)	Income tax expense
	$	2

XML

Fair Value Measurements (Tables)

6 Months Ended

Jun. 30, 2016

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value, Option, Quantitative Disclosures

The following table presents Dominion's quantitative information about Level 3 fair value measurements at June 30, 2016. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads and price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average(1)
Assets
Physical and financial forwards and futures:
Natural gas(2)	$	123	Discounted cash flow	Market price (per Dth)	(3)	(2) - 7	—
				Credit spread	(4)	1% - 6%	3	%
FTRs	6		Discounted cash flow	Market price (per MWh)	(3)	(8) - 3	1
Physical and financial options:
Natural gas	8		Option model	Market price (per Dth)	(3)	2 - 7	4
				Price volatility	(5)	20% - 42%	25	%
Total assets	$	137
Liabilities
Physical and financial forwards and futures:
Natural gas(2)	$	5	Discounted cash flow	Market price (per Dth)	(3)	(1) - 4	3
FTRs	7		Discounted cash flow	Market price (per MWh)	(3)	(2) - 5	1
Physical and financial options:
Natural gas	1		Option model	Market price (per Dth)	(3)	2 - 4	3
				Price volatility	(5)	29% - 42%	36	%
Total liabilities	$	13

(1) Averages weighted by volume.

(2) Includes basis.

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

(4) Represents credit spreads unrepresented in published markets.

(5) Represents volatilities unrepresented in published markets.

Significant Unobservable Inputs

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)
Credit spread	Asset	Increase (decrease)	Loss (gain)

Fair Value, by Balance Sheet Grouping

The following table presents Dominion’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, 2016
Assets
Derivatives:
Commodity	$	—	$	192	$	137	$	329
Interest rate	—		25		—		25
Investments(1):
Equity securities:
United States:
Large cap	2,617		—		—		2,617
Other	5		—		—		5
REIT	72		—		—		72
Non-United States:
Large cap	10		—		—		10
Fixed income:
Corporate debt instruments	—		498		—		498
United States Treasury securities and agency debentures	462		236		—		698
State and municipal	—		364		—		364
Other	—		112		—		112
Cash equivalents and other	5		—		—		5
Total assets	$	3,171	$	1,427	$	137	$	4,735
Liabilities
Derivatives:
Commodity	$	—	$	87	$	13	$	100
Interest rate	—		366		—		366
Foreign currency	—		7		—		7
Total liabilities	$	—	$	460	$	13	$	473
At December 31, 2015

Assets
Derivatives:
Commodity	$	1	$	249	$	114	$	364
Interest rate	—		24		—		24
Investments(1):
Equity securities:
United States:
Large cap	2,547		—		—		2,547
Other	5		—		—		5
REIT	63		—		—		63
Non-United States:
Large cap	10		—		—		10
Fixed income:
Corporate debt instruments	—		437		—		437
United States Treasury securities and agency debentures	458		201		—		659
State and municipal	—		376		—		376
Other	—		100		—		100
Cash equivalents and other	2		2		—		4
Total assets	$	3,086	$	1,389	$	114	$	4,589
Liabilities
Derivatives:
Commodity	$	—	$	141	$	19	$	160
Interest rate	—		183		—		183
Total liabilities	$	—	$	324	$	19	$	343

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Beginning balance	$	109		$	76		$	95		$	107
Total realized and unrealized gains (losses):
Included in earnings	(10		)	(5		)	(17		)	10
Included in other comprehensive income (loss)	—			(1		)	3			(12		)
Included in regulatory assets/liabilities	15			(5		)	32			(29		)
Settlements	10			6			18			(8		)
Transfers out of Level 3	—			—			(7		)	3
Ending balance	$	124		$	71		$	124		$	71

Fair Value, Unobservable Inputs, Gain (Loss) Included In Earnings

The following table presents Dominion's classification of gains and losses included in earnings in the Level 3 fair value category. 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 months ended June 30, 2016 and 2015.

	Operating Revenue		Electric Fuel and Other Energy-Related Purchases			Total
(millions)
Three Months Ended June 30, 2016
Total gains (losses) included in earnings	$	—	$	(10	)	$	(10	)
Three Months Ended June 30, 2015
Total gains (losses) included in earnings	$	—	$	(5	)	$	(5	)
Six Months Ended June 30, 2016
Total gains (losses) included in earnings	$	—	$	(17	)	$	(17	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date	—		—			—
Six Months Ended June 30, 2015
Total gains (losses) included in earnings	$	2	$	8		$	10
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date	1		(1		)	—

Cost and Fair Value of Financial Instruments Disclosure

For the Companies' financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:

	June 30, 2016				December 31, 2015
	Carrying Amount		Estimated Fair Value(1)		Carrying Amount		Estimated Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	22,754	$	25,400	$	21,873	$	23,210
Junior subordinated notes(3)	2,399		2,310		1,340		1,192
Remarketable subordinated notes(3)	982		1,037		2,080		2,129
Virginia Power
Long-term debt, including securities due within one year(3)	$	9,661	$	11,329	$	9,368	$	10,400
Dominion Gas
Long-term debt, including securities due within one year(4)	$	3,941	$	4,116	$	3,269	$	3,299

(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 and/or premium, and foreign currency remeasurement adjustments. At June 30, 2016 and December 31, 2015, includes the valuation of certain fair value hedges associated with fixed rate debt of $21 million and $7 million, respectively.

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

(4) Carrying amount includes amounts which represent the unamortized debt issuance costs, discount and/or premium, and foreign currency remeasurement adjustments.

Virginia Electric and Power Company

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value, Option, Quantitative Disclosures

The following table presents Virginia Power's quantitative information about Level 3 fair value measurements at June 30, 2016. The range and weighted average are presented in dollars for market price inputs and percentages for credit spreads and price volatility.

	Fair Value (millions)		Valuation Techniques	Unobservable Input		Range	Weighted Average(1)
Assets
Physical and financial forwards and futures:
Natural gas(2)	$	121	Discounted cash flow	Market price (per Dth)	(3)	(2) - 7	—
				Credit spread	(4)	1% - 6%	3	%
FTRs	6		Discounted cash flow	Market price (per MWh)	(3)	(8) - 3	1
Physical and financial options:
Natural gas	5		Option model	Market price (per Dth)	(3)	2 - 7	4
				Price volatility	(5)	20% - 33%	24	%
Total assets	$	132
Liabilities
Physical and financial forwards and futures:
FTRs	$	7	Discounted cash flow	Market price (per MWh)	(3)	(2) - 5	1
Total liabilities	$	7

(1) Averages weighted by volume.

(2) Includes basis.

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

(4) Represents credit spreads unrepresented in published markets.

(5) Represents volatilities unrepresented in published markets.

Significant Unobservable Inputs

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

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

Fair Value, by Balance Sheet Grouping

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, 2016
Assets
Derivatives:
Commodity	$	—	$	31	$	132	$	163
Investments(1):
Equity securities:
United States large cap	1,137		—		—		1,137
REIT	72		—		—		72
Fixed income:
Corporate debt instruments	—		283		—		283
United States Treasury securities and agency debentures	166		111		—		277
State and municipal	—		159		—		159
Other	—		48		—		48
Total assets	$	1,375	$	632	$	132	$	2,139
Liabilities
Derivatives:
Commodity	$	—	$	10	$	7	$	17
Interest rate	—		257		—		257
Total liabilities	$	—	$	267	$	7	$	274
At December 31, 2015
Assets
Derivatives:
Commodity	$	—	$	13	$	101	$	114
Interest rate	—		13		—		13
Investments(1):
Equity securities:
United States large cap	1,100		—		—		1,100
REIT	63		—		—		63
Fixed income:
Corporate debt instruments	—		238		—		238
United States Treasury securities and agency debentures	180		79		—		259
State and municipal	—		175		—		175
Other	—		34		—		34
Total assets	$	1,343	$	552	$	101	$	1,996
Liabilities
Derivatives:
Commodity	$	—	$	19	$	8	$	27
Interest rate	—		59		—		59
Total liabilities	$	—	$	78	$	8	$	86

(1) Includes investments held in the nuclear decommissioning and rabbi trusts.

Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

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 June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
(millions)
Beginning balance	$	110		$	78		$	93		$	102
Total realized and unrealized gains (losses):
Included in earnings	(9		)	(5		)	(17		)	8
Included in regulatory assets/liabilities	15			(5		)	32			(29		)
Settlements	9			5			17			(8		)
Ending balance	$	125		$	73		$	125		$	73

Dominion Gas Holdings, LLC

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Fair Value, by Balance Sheet Grouping

The following table presents Dominion 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, 2016
Assets
Commodity	$	—	$	3	$	—	$	3
Total Assets	$	—	$	3	$	—	$	3
Liabilities
Commodity	$	—	$	5	$	—	$	5
Foreign currency	—		7		—		7
Total liabilities	$	—	$	12	$	—	$	12
At December 31, 2015
Assets
Commodity	$	—	$	5	$	6	$	11
Total Assets	$	—	$	5	$	6	$	11
Liabilities
Interest rate	$	—	$	14	$	—	$	14
Total liabilities	$	—	$	14	$	—	$	14

Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation

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

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016			2015
(millions)
Beginning balance	$	—	$	—		$	6		$	2
Total realized and unrealized gains (losses):
Included in earnings	—		(1		)	—			1
Included in other comprehensive income (loss)	—		—			2			(12		)
Settlements	—		—			—			(1		)
Transfers out of Level 3	—		—			(8		)	9
Ending balance	$	—	$	(1	)	$	—		$	(1	)

XML

Derivatives and Hedge Accounting Activities (Tables)

6 Months Ended

Jun. 30, 2016

Derivative [Line Items]

Offsetting Assets

The tables below present Dominion's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:

	June 30, 2016						December 31, 2015
	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	$	231	$	—	$	231	$	217	$	—	$	217
Exchange	91		—		91		138		—		138
Interest rate contracts:
Over-the-counter	25		—		25		24		—		24
Total derivatives, subject to a master netting or similar arrangement	347		—		347		379		—		379
Total derivatives, not subject to a master netting or similar arrangement	7		—		7		9		—		9
Total	$	354	$	—	$	354	$	388	$	—	$	388

			June 30, 2016								December 31, 2015
			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	$	231	$	16	$	—	$	215	$	217	$	37	$	—	$	180
Exchange	91		63		—		28		138		82		—		56
Interest rate contracts:
Over-the-counter	25		15		—		10		24		22		—		2
Total	$	347	$	94	$	—	$	253	$	379	$	141	$	—	$	238

Offsetting Liabilities

	June 30, 2016						December 31, 2015
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	32	$	—	$	32	$	70	$	—	$	70
Exchange	63		—		63		82		—		82
Interest rate contracts:
Over-the-counter	366		—		366		183		—		183
Foreign currency contracts:
Over-the-counter	7		—		7		—		—		—
Total derivatives, subject to a master netting or similar arrangement	468		—		468		335		—		335
Total derivatives, not subject to a master netting or similar arrangement	5		—		5		8		—		8
Total	$	473	$	—	$	473	$	343	$	—	$	343

			June 30, 2016								December 31, 2015
			Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Commodity contracts:
Over-the-counter	$	32	$	16	$	1	$	15	$	70	$	37	$	—	$	33
Exchange	63		63		—		—		82		82		—		—
Interest rate contracts:
Over-the-counter	366		15		—		351		183		22		—		161
Foreign currency contracts:
Over-the-counter	7		—		—		7		—		—		—		—
Total	$	468	$	94	$	1	$	373	$	335	$	141	$	—	$	194

Schedule of Volume of Derivative Activity

The following table presents the volume of Dominion’s derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)	125		38
Basis	190		580
Electricity (MWh):
Fixed price	11,749,639		1,978,640
FTRs	99,882,813		—
Liquids (Gal)(2)	59,807,554		—
Interest rate(3)	$	2,400,000,000	$	2,100,000,000
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.

Cash Flow Hedges Included Accumulated Other Comprehensive Income (Loss)

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Dominion’s Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
Gas	$	10		$	9		22 months
Electricity	65			65			18 months
Other	(1		)	(1		)	9 months
Interest rate	(312		)	(23		)	381 months
Foreign currency	(3		)	(3		)	120 months
Total	$	(241	)	$	47

Fair Value of Derivatives

The following table presents the fair values of Dominion’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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	67	$	121	$	188
Interest rate	4		—		4
Total current derivative assets(1)	71		121		192
Noncurrent Assets
Commodity	6		135		141
Interest rate	21		—		21
Total noncurrent derivative assets(2)	27		135		162
Total derivative assets	$	98	$	256	$	354
LIABILITIES
Current Liabilities
Commodity	$	27	$	61	$	88
Interest rate	178		—		178

Foreign currency	5		—		5
Total current derivative liabilities(3)	210		61		271
Noncurrent Liabilities
Commodity	5		7		12
Interest rate	188		—		188
Foreign currency	2		—		2
Total noncurrent derivative liabilities(4)	195		7		202
Total derivative liabilities	$	405	$	68	$	473
At December 31, 2015
ASSETS
Current Assets
Commodity	$	101	$	151	$	252
Interest rate	3		—		3
Total current derivative assets(1)	104		151		255
Noncurrent Assets
Commodity	3		109		112
Interest rate	21		—		21
Total noncurrent derivative assets(2)	24		109		133
Total derivative assets	$	128	$	260	$	388
LIABILITIES
Current Liabilities
Commodity	$	32	$	116	$	148
Interest rate	164		—		164
Total current derivative liabilities(3)	196		116		312
Noncurrent Liabilities
Commodity	—		12		12
Interest rate	19		—		19
Total noncurrent derivative liabilities(4)	19		12		31
Total derivative liabilities	$	215	$	128	$	343

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

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

(3) Current derivative liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.

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

Gains and Losses on Derivatives in Cash Flow Hedging Relationships

The following tables present the gains and losses on Dominion'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, 2016
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	87
Purchased gas				(2		)
Electric fuel and other energy-related purchases				(3		)
Total commodity	$	12		$	82		$	—
Interest rate(3)	(23		)	(8		)	(108		)
Foreign currency(4)	(7		)	(2		)	—
Total	$	(18	)	$	72		$	(108	)
Three Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	107
Purchased gas				(2		)
Total commodity	$	94		$	105		$	—
Interest rate(3)	57			(3		)	(91		)
Total	$	151		$	102		$	(91	)
Six Months Ended June 30, 2016
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	201
Purchased gas				(8		)
Electric fuel and other energy-related purchases				(6		)
Total commodity	$	185		$	187		$	—
Interest rate(3)	(110		)	(11		)	(241		)
Foreign currency(4)	(7		)	(2		)	—
Total	$	68		$	174		$	(241	)
Six Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Operating revenue				$	15
Purchased gas				(7		)
Electric fuel and other energy-related purchases				1
Total commodity	$	54		$	9		$	3
Interest rate(3)	(1		)	(5		)	42
Total	$	53		$	4		$	45

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

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

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

Schedule of Derivatives not Designated as Hedging Instruments

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended June 30,						Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015			2016			2015
(millions)
Derivative type and location of gains (losses):
Commodity:
Operating revenue	$	(8	)	$	15		$	(6	)	$	18
Purchased gas	8			(7		)	7			(9		)
Electric fuel and other energy-related purchases	(9		)	3			(31		)	9
Other operations and maintenance	1			—			—			—
Total	$	(8	)	$	11		$	(30	)	$	18

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

Virginia Electric and Power Company

Derivative [Line Items]

Offsetting Assets

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, 2016						December 31, 2015
	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	$	127	$	—	$	127	$	101	$	—	$	101
Interest rate contracts:
Over-the-counter	—		—		—		13		—		13
Total derivatives, subject to a master netting or similar arrangement	127		—		127		114		—		114
Total derivatives, not subject to a master netting or similar arrangement	36		—		36		13		—		13
Total	$	163	$	—	$	163	$	127	$	—	$	127

			June 30, 2016								December 31, 2015
			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	$	127	$	7	$	—	$	120	$	101	$	3	$	—	$	98
Interest rate contracts:
Over-the-counter	—		—		—		—		13		10		—		3
Total	$	127	$	7	$	—	$	120	$	114	$	13	$	—	$	101

Offsetting Liabilities

	June 30, 2016						December 31, 2015
	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	$	14	$	—	$	14	$	5	$	—	$	5
Interest rate contracts:
Over-the-counter	257		—		257		59		—		59
Total derivatives, subject to a master netting or similar arrangement	271		—		271		64		—		64
Total derivatives, not subject to a master netting or similar arrangement	3		—		3		22		—		22
Total	$	274	$	—	$	274	$	86	$	—	$	86

			June 30, 2016								December 31, 2015
			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	$	14	$	7	$	1	$	6	$	5	$	3	$	—	$	2
Interest rate contracts:
Over-the-counter	257		—		—		257		59		10		—		49
Total	$	271	$	7	$	1	$	263	$	64	$	13	$	—	$	51

Schedule of Volume of Derivative Activity

The following table presents the volume of Virginia Power’s derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price(1)	42		16
Basis	67		538
Electricity (MWh):
FTRs	97,710,646		—
Interest rate	$	700,000,000	$	1,100,000,000

(1) Includes options.

Cash Flow Hedges Included Accumulated Other Comprehensive Income (Loss)

The following table presents selected information related to gains (losses) on cash flow hedges included in AOCI in Virginia Power’s Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Interest rate	$	(21	)	$	(1	)	381 months
Total	$	(21	)	$	(1	)

Fair Value of Derivatives

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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	—	$	34	$	34
Total current derivative assets(1)	—		34		34
Noncurrent Assets
Commodity	—		129		129
Total noncurrent derivative assets(2)	—		129		129
Total derivative assets	$	—	$	163	$	163
LIABILITIES
Current Liabilities
Commodity	$	—	$	12	$	12
Interest rate	69		—		69
Total current derivative liabilities(3)	69		12		81
Noncurrent Liabilities
Commodity	—		5		5
Interest rate	188		—		188
Total noncurrent derivatives liabilities (4)	188		5		193
Total derivative liabilities	$	257	$	17	$	274
At December 31, 2015
ASSETS
Current Assets
Commodity	$	—	$	18	$	18
Total current derivative assets(1)	—		18		18
Noncurrent Assets
Commodity	—		96		96
Interest rate	13		—		13
Total noncurrent derivative assets(2)	13		96		109
Total derivative assets	$	13	$	114	$	127
LIABILITIES
Current Liabilities
Commodity	$	—	$	23	$	23
Interest rate	57		—		57
Total current derivative liabilities(3)	57		23		80
Noncurrent Liabilities
Commodity	—		4		4
Interest rate	2		—		2
Total noncurrent derivative liabilities(4)	2		4		6
Total derivative liabilities	$	59	$	27	$	86

(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.

Gains and Losses on Derivatives in Cash Flow Hedging Relationships

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, 2016
Derivative type and location of gains (losses):
Interest rate(3)	$	(10	)	$	—		$	(108	)
Total	$	(10	)	$	—		$	(108	)
Three Months Ended June 30, 2015
Derivative type and location of gains (losses):
Interest rate(3)	$	11		$	—		$	91
Total	$	11		$	—		$	91
Six Months Ended June 30, 2016
Derivative type and location of gains (losses):
Interest rate(3)	$	(24	)	$	(1	)	$	(241	)
Total	$	(24	)	$	(1	)	$	(241	)
Six Months Ended June 30, 2015
Derivative type and location of gains (losses):
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Total commodity	$	—		$	(1	)	$	3
Interest rate(3)	5			—			42
Total	$	5		$	(1	)	$	45

(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.

Schedule of Derivatives not Designated as Hedging Instruments

	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015		2016			2015
(millions)
Derivative type and location of gains (losses):
Commodity(2)	$	(10	)	$	5	$	(30	)	$	12
Total	$	(10	)	$	5	$	(30	)	$	12

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

(2) Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.

Dominion Gas Holdings, LLC

Derivative [Line Items]

Offsetting Assets

The tables below present Dominion Gas' derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting.

	June 30, 2016						December 31, 2015
	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	$	3	$	—	$	3	$	11	$	—	$	11
Total derivatives, subject to a master netting or similar arrangement	$	3	$	—	$	3	$	11	$	—	$	11

			June 30, 2016								December 31, 2015
			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	$	3	$	3	$	—	$	—	$	11	$	—	$	—	$	11
Total	$	3	$	3	$	—	$	—	$	11	$	—	$	—	$	11

Offsetting Liabilities

	June 30, 2016						December 31, 2015
	Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Gross Amounts of Recognized Liabilities		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet
(millions)
Commodity contracts:
Over-the-counter	$	5	$	—	$	5	$	—	$	—	$	—
Interest rate contracts:
Over-the-counter	—		—		—		14		—		14
Foreign currency contracts:
Over-the-counter	7		—		7		—		—		—
Total derivatives, subject to a master netting or similar arrangement	$	12	$	—	$	12	$	14	$	—	$	14

			June 30, 2016								December 31, 2015
			Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Net Amounts of Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
(millions)
Commodity contracts
Over-the-counter	$	5	$	3	$	—	$	2	$	—	$	—	$	—	$	—
Interest rate contracts:
Over-the-counter	—		—		—		—		14		—		—		14
Foreign currency contracts:
Over-the-counter	7		—		—		7		—		—		—		—
Total	$	12	$	3	$	—	$	9	$	14	$	—	$	—	$	14

Schedule of Volume of Derivative Activity

The following table presents the volume of Dominion Gas' derivative activity at June 30, 2016. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions, except in the case of offsetting transactions, for which they represent the absolute value of the net volume of their long and short positions.

	Current		Noncurrent
Natural Gas (bcf):
Fixed price	7		—
Basis	7		—
NGLs (Gal)	52,247,554		—
Foreign currency(1)	$	—	$	280,000,000

(1) Maturity is determined based on final settlement period. Euro equivalent volumes are €250,000,000.

Cash Flow Hedges Included Accumulated Other Comprehensive Income (Loss)

The following table presents selected information related to losses on cash flow hedges included in AOCI in Dominion Gas' Consolidated Balance Sheet at June 30, 2016:

	AOCI After-Tax			Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax			Maximum Term
(millions)
Commodities:
NGLs	$	(1	)	$	(1	)	9 months
Interest rate	(30		)	(4		)	342 months
Foreign currency	(3		)	(3		)	120 months
Total	$	(34	)	$	(8	)

Fair Value of Derivatives

The following tables present the fair values of Dominion 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)
At June 30, 2016
ASSETS
Current Assets
Commodity	$	2	$	1	$	3
Total current derivative assets(1)	2		1		3
Total derivative assets	$	2	$	1	$	3
LIABILITIES
Current Liabilities
Commodity	$	4	$	1	$	5
Foreign currency	5		—		5
Total current derivative liabilities(3)	9		1		10
Noncurrent Liabilities
Foreign currency	2		—		2
Total noncurrent derivative liabilities(4)	2		—		2
Total derivative liabilities	$	11	$	1	$	12
At December 31, 2015
ASSETS
Current Assets
Commodity	$	10	$	—	$	10
Total current derivative assets(1)	10		—		10
Noncurrent Assets
Commodity	1		—		1
Total noncurrent derivatives assets(2)	1		—		1
Total derivative assets	$	11	$	—	$	11
LIABILITIES
Noncurrent Liabilities
Interest rate	$	14	$	—	$	14
Total noncurrent derivative liabilities(4)	14		—		14
Total derivative liabilities	$	14	$	—	$	14

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

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

(3) Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.

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

Gains and Losses on Derivatives in Cash Flow Hedging Relationships

The following table presents the gains and losses on Dominion 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, 2016
Derivative Type and Location of Gains (Losses):
Commodity	$	(6	)	$	—
Foreign currency(3)	(7		)	(2		)
Total	$	(13	)	$	(2	)
Three Months Ended June 30, 2015
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue				$	1
Total commodity	$	—		$	1
Interest rate(2)	4			—
Total	$	4		$	1
Six Months Ended June 30, 2016
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	4
Total commodity	$	(7	)	$	4
Interest rate(2)	(9		)	—
Foreign currency(3)	(7		)	(2		)
Total	$	(23	)	$	2
Six Months Ended June 30, 2015
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	1
Total commodity	$	(2	)	$	1
Total	$	(2	)	$	1

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

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

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

Schedule of Derivatives not Designated as Hedging Instruments

	Amount of Gain (Loss) Recognized in Income on Derivatives
	Three Months Ended June 30,					Six Months Ended June 30,
Derivatives Not Designated as Hedging Instruments	2016			2015		2016			2015
(millions)
Derivative Type and Location of Gains (Losses):
Commodity:
Operating revenue	$	(2	)	$	3	$	(2	)	$	4
Total	$	(2	)	$	3	$	(2	)	$	4

XML

Investments (Tables)

6 Months Ended

Jun. 30, 2016

Gain (Loss) on Investments [Line Items]

Available-For-Sale Securities

Dominion’s decommissioning trust funds are summarized below:

	Amortized Cost			Total  Unrealized Gains(1)		Total  Unrealized Losses(1)				Fair Value
(millions)
At June 30, 2016
Marketable equity securities:
United States large cap	$	1,326		$	1,251	$	—			$	2,577
REIT	61			11		—				72
Marketable debt securities:
Corporate bonds	474			25		(1		)		498
United States Treasury securities and agency debentures	672			26		—				698
State and municipal	290			31		—				321
Other	108			—		—				108
Cost method investments	69			—		—				69
Cash equivalents and other(2)	(12		)	—		—				(12		)
Total	$	2,988		$	1,344	$	(1	)	(3)	$	4,331
At December 31, 2015
Marketable equity securities:
United States large cap	$	1,295		$	1,213	$	—			$	2,508
REIT	59			4		—				63
Marketable debt securities:
Corporate bonds	433			11		(7		)		437
United States Treasury securities and agency debentures	654			8		(4		)		658
State and municipal	312			22		—				334
Other	99			—		—				99
Cost method investments	70			—		—				70
Cash equivalents and other(2)	14			—		—				14
Total	$	2,936		$	1,258	$	(11	)	(3)	$	4,183

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

(2) Includes pending purchases of securities of $16 million and pending sales of securities of $12 million at June 30, 2016 and December 31, 2015, respectively.

(3) The fair value of securities in an unrealized loss position was $90 million and $592 million at June 30, 2016 and December 31, 2015, respectively.

Investments Classified by Contractual Maturity Date

The fair value of Dominion’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2016 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	212
Due after one year through five years	458
Due after five years through ten years	390
Due after ten years	565
Total	$	1,625

Marketable Securities

Presented below is selected information regarding Dominion’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Proceeds from sales	$	341	$	243	$	709	$	580
Realized gains(1)	37		44		62		100
Realized losses(1)	15		12		34		29

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

Virginia Electric and Power Company

Gain (Loss) on Investments [Line Items]

Available-For-Sale Securities

Virginia Power’s decommissioning trust funds are summarized below:

	Amortized Cost			Total  Unrealized Gains(1)		Total  Unrealized Losses(1)				Fair Value
(millions)
At June 30, 2016
Marketable equity securities:
United States large cap	$	590		$	546	$	—			$	1,136
REIT	61			11		—				72
Marketable debt securities:
Corporate bonds	271			13		(1		)		283
United States Treasury securities and agency debentures	270			7		—				277
State and municipal	141			17		—				158
Other	48			—		—				48
Cost method investments	69			—		—				69
Cash equivalents and other(2)	(13		)	—		—				(13		)
Total	$	1,437		$	594	$	(1	)	(3)	$	2,030
At December 31, 2015
Marketable equity securities:
United States large cap	$	574		$	525	$	—			$	1,099
REIT	59			4		—				63
Marketable debt securities:
Corporate bonds	237			5		(4		)		238
United States Treasury securities and agency debentures	260			1		(2		)		259
State and municipal	162			13		(1		)		174
Other	34			—		—				34
Cost method investments	70			—		—				70
Cash equivalents and other(2)	8			—		—				8
Total	$	1,404		$	548	$	(7	)	(3)	$	1,945

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

(2) Includes pending purchases of securities of $13 million and pending sales of securities of $8 million at June 30, 2016 and December 31, 2015, respectively.

(3) The fair value of securities in an unrealized loss position was $66 million and $281 million at June 30, 2016 and December 31, 2015, respectively.

Investments Classified by Contractual Maturity Date

The fair value of Virginia Power’s marketable debt securities held in nuclear decommissioning trust funds at June 30, 2016 by contractual maturity is as follows:

	Amount
(millions)
Due in one year or less	$	71
Due after one year through five years	207
Due after five years through ten years	218
Due after ten years	270
Total	$	766

Marketable Securities

Presented below is selected information regarding Virginia Power’s marketable equity and debt securities held in nuclear decommissioning trust funds.

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Proceeds from sales	$	154	$	76	$	347	$	209
Realized gains(1)	18		19		30		37
Realized losses(1)	7		4		17		15

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

XML

Regulatory Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2016

Regulatory Assets and Liabilities Disclosure [Abstract]

Schedule Of Regulatory Assets And Liabilities

Regulatory assets and liabilities include the following:

	June 30, 2016		December 31, 2015
(millions)
Dominion
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	95	$	90
Deferred nuclear refueling outage costs(2)	61		75
Deferred cost of fuel used in electric generation(3)	5		111
Other	60		75
Regulatory assets-current(4)	221		351
Unrecognized pension and other postretirement benefit costs(5)	992		1,015
Derivatives(6)	351		110
Deferred rate adjustment clause costs(1)	342		295
PJM transmission rates(7)	192		192
Income taxes recoverable through future rates(8)	137		126

Other	136		127
Regulatory assets-non-current	2,150		1,865
Total regulatory assets	$	2,371	$	2,216
Regulatory liabilities:
Deferred cost of fuel used in electric generation(3)	$	89	$	—
PIPP(9)	25		46
Other	47		54
Regulatory liabilities-current(10)	161		100
Provision for future cost of removal and AROs(11)	1,148		1,120
Nuclear decommissioning trust(12)	852		804
Derivatives(6)	108		79
Deferred cost of fuel used in electric generation(3)	26		97
Other	184		185
Regulatory liabilities-non-current	2,318		2,285
Total regulatory liabilities	$	2,479	$	2,385
Virginia Power
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	72	$	80
Deferred nuclear refueling outage costs(2)	61		75
Deferred cost of fuel used in electric generation(3)	5		111
Other	55		60
Regulatory assets-current	193		326
Derivatives(6)	351		110
Deferred rate adjustment clause costs(1)	254		213
PJM transmission rates(7)	192		192
Income taxes recoverable through future rates(8)	106		97
Other	63		55
Regulatory assets-non-current	966		667
Total regulatory assets	$	1,159	$	993
Regulatory liabilities:
Deferred cost of fuel used in electric generation(3)	$	89	$	—
Other	23		35
Regulatory liabilities-current(10)	112		35
Provision for future cost of removal(11)	913		890
Nuclear decommissioning trust(12)	852		804
Derivatives(6)	108		79
Deferred cost of fuel used in electric generation(3)	26		97
Other	57		59
Regulatory liabilities-non-current	1,956		1,929
Total regulatory liabilities	$	2,068	$	1,964
Dominion Gas
Regulatory assets:
Deferred rate adjustment clause costs(1)	$	23	$	10
Other	2		13
Regulatory assets-current(4)	25		23
Unrecognized pension and other postretirement benefit costs(5)	277		282

Deferred rate adjustment clause costs(1)	88		82
Income taxes recoverable through future rates(8)	20		20
Other	66		65
Regulatory assets-non-current(13)	451		449
Total regulatory assets	$	476	$	472
Regulatory liabilities:
PIPP(9)	$	25	$	46
Other	18		9
Regulatory liabilities-current(10)	43		55
Provision for future cost of removal and AROs(11)	174		170
Other	39		31
Regulatory liabilities-non-current(14)	213		201
Total regulatory liabilities	$	256	$	256

(1) Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 12 for more information.

(2) 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.

(3) Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power's generation operations. See Note 12 for more information.

(4) Current regulatory assets are presented in other current assets in Dominion's and Dominion Gas' Consolidated Balance Sheets.

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

(6) 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.

(7) Reflects amounts related to PJM transmission cost allocation matter. See Note 12 for more information.

(8) Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes.

(9) 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.

(10) Current regulatory liabilities are presented in other current liabilities in the Companies' Consolidated Balance Sheets.

(11) 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.

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

(13) Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

(14) Noncurrent regulatory liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

XML

Significant Financing Transactions (Tables)

6 Months Ended

Jun. 30, 2016

Debt Instrument [Line Items]

Schedule of Line of Credit Facilities

At June 30, 2016, Dominion’s commercial paper and letters of credit outstanding, as well as its capacity available under credit facilities, were as follows:

	Facility Limit		Outstanding Commercial Paper		Outstanding Letters of Credit		Facility Capacity Available
(millions)
Joint revolving credit facility(1)	$	5,000	$	3,437	$	—	$	1,563
Joint revolving credit facility(1)	500		—		52		448
Total	$	5,500	$	3,437	$	52	$	2,011

(1) In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities can be used 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.

Virginia Electric and Power Company

Debt Instrument [Line Items]

Schedule of Line of Credit Facilities

At June 30, 2016, Virginia Power’s share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Dominion Gas, were as follows:

	Facility Limit(1)		Outstanding Commercial Paper		Outstanding Letters of Credit
(millions)
Joint revolving credit facility(1)	$	5,000	$	1,423	$	—
Joint revolving credit facility(1)	500		—		—
Total	$	5,500	$	1,423	$	—

(1) The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Virginia Power was $2.0 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $2.0 billion (or the sub-limit, whichever is less) of letters of credit.

Dominion Gas Holdings, LLC

Debt Instrument [Line Items]

Schedule of Line of Credit Facilities

At June 30, 2016, Dominion Gas' share of commercial paper and letters of credit outstanding under its joint credit facilities with Dominion and Virginia Power were as follows:

	Facility Limit(1)		Outstanding Commercial Paper		Outstanding Letters of Credit
(millions)
Joint revolving credit facility(1)	$	1,000	$	238	$	—
Joint revolving credit facility(1)	500		—		—
Total	$	1,500	$	238	$	—

(1) A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Dominion Gas was $1.0 billion. If Dominion 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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.

XML

Commitments and Contingencies (Tables)

6 Months Ended

Jun. 30, 2016

Commitments and Contingencies Disclosure [Abstract]

Schedule Of Subsidiary Guarantees

At June 30, 2016, Dominion had issued the following subsidiary guarantees:

	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	27	$	27
Commodity transactions(3)	2,074		864
Nuclear obligations(4)	189		81
Cove Point(5)	1,900		—
Solar(6)	1,514		244
Other(7)	420		28
Total	$	6,124	$	1,244

(1) Represents the estimated portion of the guarantee's stated limit that is utilized as of June 30, 2016 based upon prevailing economic conditions and fact patterns specific to each guarantee arrangement. For those guarantees related to obligations that are recorded as liabilities by Dominion's subsidiaries, the value includes the recorded amount.

(2) Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, Dominion would be obligated to repay such amounts.

(3) Guarantees related to commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and related commodities and services. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion would be obligated to satisfy such obligation. Dominion and its subsidiaries receive similar guarantees as collateral for credit extended to others. The value provided includes certain guarantees that do not have stated limits.

(4) Guarantees related to certain DEI subsidiaries' potential retrospective premiums that could be assessed if there is a nuclear incident under Dominion's nuclear insurance programs and guarantees for a DEI subsidiary's and Virginia Power's commitment to buy nuclear fuel. Excludes Dominion's agreement to provide up to $150 million and $60 million to two DEI subsidiaries to pay the operating expenses of Millstone nuclear power station (in the event of a prolonged outage) and Kewaunee nuclear power station, respectively, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee nuclear power station also provides for funds through the completion of decommissioning.

(5) Guarantees related to Cove Point, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.

(6) Includes guarantees to facilitate the development of solar projects including guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects. 

(7) Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of June 30, 2016, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $45 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.

XML

Related-Party Transactions (Tables)

6 Months Ended

Jun. 30, 2016

Virginia Electric and Power Company

Related Party Transaction [Line Items]

Transactions With Affiliates

Presented below are Virginia Power's significant transactions with DRS and other affiliates:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Commodity purchases from affiliates	$	99	$	94	$	244	$	346
Services provided by affiliates(1)	102		107		242		217
Services provided to affiliates	7		5		12		10

(1) Includes capitalized expenditures of $38 million for both the three months ended June 30, 2016 and 2015, respectively, and $77 million and $73 million for the six months ended June 30, 2016 and 2015, respectively.

Dominion Gas Holdings, LLC

Related Party Transaction [Line Items]

Schedule of Related Party Transactions

Dominion Gas transacts with affiliates for certain quantities of natural gas and other commodities at market prices in the ordinary course of business. Additionally, Dominion Gas provides transportation and storage services to affiliates. Dominion Gas also enters into certain other contracts with affiliates, which are presented separately from contracts involving commodities or services. As of June 30, 2016 and December 31, 2015, all of Dominion Gas' commodity derivatives were with affiliates. See Notes 7 and 9 for more information.

Dominion Gas participates in certain Dominion benefit plans as described in Note 18. In Dominion Gas' Consolidated Balance Sheets at June 30, 2016 and December 31, 2015, amounts due from Dominion associated with these benefit plans included in noncurrent pension and other postretirement benefit assets were $674 million and $652 million, respectively, and amounts due to Dominion at June 30, 2016 and December 31, 2015 included in other deferred credits and other liabilities were immaterial.

DRS and other affiliates provide accounting, legal, finance and certain administrative and technical services to Dominion Gas. Dominion Gas provides certain services to related parties, including technical services. The amounts recognized for these services were as follows:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
(millions)
Purchases of natural gas and transportation and storage services from affiliates	$	2	$	2	$	5	$	4
Sales of natural gas and transportation and storage services to affiliates	18		17		35		35
Services provided by related parties(1)	33		34		72		68
Services provided to related parties (2)	33		25		60		45

(1) Includes capitalized expenditures of $14 million and $15 million for the three months ended June 30, 2016 and 2015, respectively, and $24 million for both the six months ended June 30, 2016 and 2015.

(2) Amounts primarily attributable to Atlantic Coast Pipeline.

The following table presents affiliated and related-party activity reflected in Dominion Gas' Consolidated Balance Sheets:

	June 30, 2016		December 31, 2015
(millions)
Other receivables(1)	$	8	$	7
Customer receivables from related parties	10		4
Imbalances receivable from affiliates(2)	3		1
Affiliated notes receivable(3)	16		14

(1) Represents amounts due from Atlantic Coast Pipeline, a related-party VIE.

(2) Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.

(3) Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

XML

Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2016

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Benefit Cost

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

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
(millions)
Three Months Ended June 30,
Service cost	$	28		$	31		$	8		$	10
Interest cost	78			72			17			16
Expected return on plan assets	(139		)	(133		)	(30		)	(30		)
Amortization of prior service cost (credit)	1			1			(7		)	(6		)
Amortization of net actuarial loss	27			40			2			2
Net periodic benefit cost (credit)	$	(5	)	$	11		$	(10	)	$	(8	)
Six Months Ended June 30,
Service cost	$	57		$	63		$	16		$	20
Interest cost	155			144			34			33
Expected return on plan assets	(278		)	(266		)	(59		)	(59		)
Amortization of prior service cost (credit)	1			1			(14		)	(13		)
Amortization of net actuarial loss	55			80			3			3
Net periodic benefit cost (credit)	$	(10	)	$	22		$	(20	)	$	(16	)

Dominion Gas Holdings, LLC

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Benefit Cost

The components of Dominion Gas' provision for net periodic benefit credit for employees represented by collective bargaining units were as follows:

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
(millions)
Three Months Ended June 30,
Service cost	$	4		$	4		$	2		$	1
Interest cost	7			7			4			4
Expected return on plan assets	(34		)	(32		)	(7		)	(6		)
Amortization of net actuarial loss	4			5			1			—
Net periodic benefit credit	$	(19	)	$	(16	)	$	—		$	(1	)
Six Months Ended June 30,
Service cost	$	7		$	7		$	3		$	3
Interest cost	15			14			7			7
Expected return on plan assets	(67		)	(63		)	(12		)	(12		)
Amortization of net actuarial loss	7			10			1			1
Net periodic benefit credit	$	(38	)	$	(32	)	$	(1	)	$	(1	)

XML

Operating Segments (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting Information [Line Items]

Segment Reporting Disclosure Other Information

A description of the operations included in the Companies’ primary operating segments is as follows:

Primary Operating Segment	Description of Operations	Dominion	Virginia Power	Dominion Gas
DVP	Regulated electric distribution	X	X
	Regulated electric transmission	X	X
Dominion Generation	Regulated electric fleet	X	X
	Merchant electric fleet	X
Dominion Energy	Gas transmission and storage(1)	X		X
	Gas distribution and storage	X		X
	Gas gathering and processing	X		X
	LNG import and storage	X
	Nonregulated retail energy marketing(2)	X

(1) Includes remaining producer services activities for Dominion.

(2) As a result of Dominion's decision to realign its business units effective for 2015 year-end reporting, nonregulated retail energy marketing operations were moved from the Dominion Generation segment to the Dominion Energy segment.

Schedule of Segment Reporting Information, by Segment

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

	DVP		Dominion Generation(1)		Dominion Energy(1)		Corporate and Other			Adjustments/Eliminations(1)			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Total revenue from external customers	$	512	$	1,564	$	391	$	3		$	128		$	2,598
Intersegment revenue	6		2		124		133			(265		)	—
Total operating revenue	518		1,566		515		136			(137		)	2,598
Net income attributable to Dominion	104		171		162		15			—			452
Three Months Ended June 30, 2015
Total revenue from external customers	$	500	$	1,652	$	463	$	4		$	128		$	2,747
Intersegment revenue	5		6		115		144			(270		)	—
Total operating revenue	505		1,658		578		148			(142		)	2,747
Net income (loss) attributable to Dominion	117		250		129		(83		)	—			413
Six Months Ended June 30, 2016
Total revenue from external customers	$	1,068	$	3,257	$	876	$	6		$	312		$	5,519
Intersegment revenue	11		5		302		325			(643		)	—
Total operating revenue	1,079		3,262		1,178		331			(331		)	5,519
Net income (loss) attributable to Dominion	224		416		348		(12		)	—			976
Six Months Ended June 30, 2015
Total revenue from external customers	$	1,064	$	3,641	$	999	$	(9	)	$	461		$	6,156
Intersegment revenue	10		9		425		286			(730		)	—
Total operating revenue	1,074		3,650		1,424		277			(269		)	6,156
Net income (loss) attributable to Dominion	257		512		356		(176		)	—			949

(1) 2015 amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.

Virginia Electric and Power Company

Segment Reporting Information [Line Items]

Schedule of Segment Reporting Information, by Segment

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

	DVP		Dominion Generation		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Operating revenue	$	512	$	1,264	$	—		$	1,776
Net income	104		174		2			280
Three Months Ended June 30, 2015
Operating revenue	$	502	$	1,311	$	—		$	1,813
Net income (loss)	117		155		(26		)	246
Six Months Ended June 30, 2016
Operating revenue	$	1,069	$	2,597	$	—		$	3,666
Net income (loss)	222		340		(19		)	543
Six Months Ended June 30, 2015
Operating revenue	$	1,069	$	2,896	$	(15	)	$	3,950
Net income (loss)	257		345		(87		)	515

Dominion Gas Holdings, LLC

Segment Reporting Information [Line Items]

Schedule of Segment Reporting Information, by Segment

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

	Dominion Energy		Corporate and Other			Consolidated Total
(millions)
Three Months Ended June 30, 2016
Operating revenue	$	368	$	—		$	368
Net income (loss)	108		(3		)	105
Three Months Ended June 30, 2015
Operating revenue	$	395	$	—		$	395
Net income (loss)	87		(2		)	85
Six Months Ended June 30, 2016
Operating revenue	$	799	$	—		$	799
Net income (loss)	211		(8		)	203
Six Months Ended June 30, 2015
Operating revenue	$	926	$	—		$	926
Net income (loss)	251		(5		)	246

XML

Significant Accounting Policies (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016	Sep. 30, 2015
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Merchant Solar Projects
Subsidiary, Sale of Stock [Line Items]
Percentage of equity interest sold to noncontrolling interest owners	33.00%	33.00%
Four Brothers and Three Cedars
Subsidiary, Sale of Stock [Line Items]
Percentage ownership in total units	50.00%
Dominion Midstream Partners, LP
Subsidiary, Sale of Stock [Line Items]
Ownership interest percentage of limited partner interests	64.80%

XML

Acquisitions and Dispositions (Narrative) (Details) $ / shares in Units, a in Thousands				1 Months Ended										6 Months Ended	12 Months Ended
	Dec. 31, 2016 USD ($) $ / shares	Jan. 31, 2016 USD ($) a	Apr. 01, 2015 USD ($) $ / shares shares	Jul. 31, 2016 USD ($) a field	Apr. 30, 2016 USD ($) a	Jan. 31, 2016 USD ($) a	Dec. 31, 2015 USD ($) project		Sep. 30, 2015 USD ($) project MW	Jun. 30, 2015 USD ($) project MW	Mar. 31, 2015 USD ($) a field	Jan. 31, 2015 USD ($) mi	Dec. 31, 2013 USD ($) a field	Jun. 30, 2016 USD ($)	Jun. 30, 2016 USD ($)	Nov. 30, 2014 a field
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Restricted cash and cash equivalents							$ 17,000,000	[1]						$ 516,000,000	$ 516,000,000
Contributions from SunEdison to Four Brothers and Three Cedars														162,000,000
Goodwill							$ 3,294,000,000	[1]						$ 3,294,000,000	$ 3,294,000,000
Merchant Solar Projects | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of equity interest sold to noncontrolling interest owners									33.00%					33.00%	33.00%
Number of solar projects | project									24
MW Capacity | MW									425
Total number of solar projects related to potential sale | project							15
Amount of consideration		$ 117,000,000				$ 117,000,000	$ 184,000,000
Dominion Midstream Partners, LP | DCG | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Affiliate
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Amount of consideration			$ 501,000,000
Percentage of equity interests			100.00%
Dominion Midstream Partners, LP | DCG | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Affiliate | Partnership Interest
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Number of common units issued | shares			5,112,139
Value of common units issued			$ 200,000,000
Number of trading days used to determine weighted average trading price			10 days
Price per unit | $ / shares			$ 39.12
Dominion Midstream Partners, LP | DCG | Disposal Group, Disposed of by Sale, Not Discontinued Operations | Affiliate | Senior unsecured promissory note payable by Dominion Midstream | Unsecured Promissory Note Receivable
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Term of senior unsecured promissory note payable to Dominion			2 years
Amount of senior unsecured promissory note payable to Dominion			$ 301,000,000
Annual interest rate for senior unsecured promissory note payable to Dominion			0.60%
Dominion Gas Holdings, LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Goodwill							$ 542,000,000	[2]						$ 542,000,000	$ 542,000,000
Dominion Gas Holdings, LLC | Marcellus Shale | Shale development rights
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Amount of consideration		$ 5,000,000				$ 5,000,000					$ 27,000,000		$ 200,000,000
Acres of rights conveyed | a		2				2					11		79			24
Number of natural gas storage fields | field											1		1			1
Duration of conveyance of rights													9 years
Dominion Gas Holdings, LLC | Marcellus Shale | Shale development rights | Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Amount of consideration				$ 5,000,000
Acres of rights conveyed | a				2
Number of natural gas storage fields | field				1
Gain on sale of assets				$ 5,000,000
After tax gain on sale of assets				$ 3,000,000
Dominion Gas Holdings, LLC | Marcellus Shale | Shale development rights | Other operations and maintenance
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain on sale of assets						$ 5,000,000					$ 27,000,000
After tax gain on sale of assets						$ 3,000,000					$ 16,000,000
Dominion Gas Holdings, LLC | Marcellus Shale | Shale development rights | Amended Agreement to Extend Conveyance of Development Rights
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Acres of rights conveyed | a					70						9
Duration of conveyance of rights											2 years
Partial interest in remaining acres conveyed (percentage)					32.00%
Dominion Gas Holdings, LLC | Marcellus Shale | Shale development rights | Amended Agreement to Extend Conveyance of Development Rights | Other operations and maintenance
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Deferred revenue recognized from conveyance of rights					$ 35,000,000						$ 43,000,000
Deferred revenue recognized from conveyance of rights, after tax					21,000,000						$ 27,000,000
Terra Nova Renewable Partners | Call Option | Merchant Solar Projects
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage ownership in total units														67.00%	67.00%
Questar Corporation
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Liabilities incurred		$ 3,900,000,000			$ 3,140,000,000
Restricted cash and cash equivalents														$ 500,000,000	$ 500,000,000
Questar Corporation | Scenario, Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Price per share | $ / shares	$ 25
Acquisition price	$ 4,400,000,000
Debt acquired expected to remain outstanding	1,500,000,000
Termination fee to be paid by Dominion if acquisition is unapproved	154,000,000
Termination fee to be paid by Questar if acquisition is unapproved	$ 99,000,000
Four Brothers and Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage ownership in total units														50.00%	50.00%
Four Brothers and Three Cedars | Federal | Investment Tax Credits
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Percentage of expected federal investment tax credits on projects to be claimed														99.00%	99.00%
Four Brothers and Three Cedars | SunEdison, Inc
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Contributions from SunEdison to Four Brothers and Three Cedars															$ 265,000,000
Four Brothers
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Acquisition price										$ 64,000,000
Liabilities incurred										$ 62,000,000
Percentage of equity interests acquired										50.00%
Acquisition price in cash										$ 2,000,000
Number of Projects | project										4
Expected cost of projects														$ 730,000,000	730,000,000
Acquired equity										$ 64,000,000
Non-controlling interest										25,000,000
Net property, plant and equipment acquired										$ 89,000,000
MW Capacity | MW										320
Four Brothers | Four Brothers and Three Cedars | Obligation to Contribute Capital to Fund Construction of Projects
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Amount obligated to contribute to fund construction of projects														445,000,000	445,000,000
Contributions to fund projects														370,000,000	370,000,000
Four Brothers | Other Current Liabilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payable at period end														11,000,000	11,000,000
Three Cedars
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Acquisition price									$ 43,000,000
Liabilities incurred									$ 37,000,000
Percentage of equity interests acquired									50.00%
Acquisition price in cash									$ 6,000,000
Number of Projects | project									3
Expected cost of projects														425,000,000	425,000,000
Acquired equity									$ 43,000,000
Non-controlling interest									22,000,000
Net property, plant and equipment acquired									$ 65,000,000
MW Capacity | MW									210
Three Cedars | Four Brothers and Three Cedars | Obligation to Contribute Capital to Fund Construction of Projects
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Amount obligated to contribute to fund construction of projects														276,000,000	276,000,000
Contributions to fund projects														223,000,000	223,000,000
Three Cedars | Other Current Liabilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Payable at period end														$ 7,000,000	$ 7,000,000
DCG
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Acquisition price												$ 497,000,000
Percentage of equity interests acquired												100.00%
Net property, plant and equipment acquired												$ 277,000,000
Length of natural gas pipeline | mi												1,500
Goodwill												$ 250,000,000
Goodwill expected to be deductible for income tax purposes												225,000,000
Regulatory liabilities assumed												$ 38,000,000

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[2] Dominion Gas’ Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

XML

Acquisitions and Dispositions (Schedule of Acquisitions of Solar Projects) (Details) $ in Millions		1 Months Ended			2 Months Ended			6 Months Ended
		Jun. 30, 2015 USD ($) project MW	Apr. 30, 2015 USD ($) project MW		Jul. 31, 2015 USD ($)	May 31, 2015 USD ($)		Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)
Business Acquisition [Line Items]
Acquisition of solar development projects								$ 0	$ 230
EC&R NA Solar PV, LLC
Business Acquisition [Line Items]
Number of Projects | project			1
Initial Acquisition Cost	[1]		$ 66
Acquisition of solar development projects	[2]					$ 66
MW Capacity | MW			20
EDF Renewable Development, Inc.
Business Acquisition [Line Items]
Number of Projects | project		1	3	[3]
Initial Acquisition Cost	[1]	$ 68	$ 106	[3]
Acquisition of solar development projects	[2]				$ 68	$ 106	[3]
MW Capacity | MW		18	24	[3]

[1] The purchase price was primarily allocated to Property, Plant and Equipment.

[2] Includes acquisition cost.

[3] One of the projects, Marin Carport, began commercial operations in 2016.

XML

Operating Revenue (Schedule of Operating Revenue) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Electric sales:
Regulated		$ 1,718	$ 1,779	$ 3,560	$ 3,891
Nonregulated		335	351	724	757
Gas sales:
Regulated		26	31	91	147
Nonregulated		54	87	172	295
Gas transportation and storage		369	385	784	856
Other		96	114	188	210
Total operating revenue		2,598	2,747	5,519	6,156
Virginia Electric and Power Company
Electric sales:
Regulated		1,718	1,779	3,560	3,891
Gas sales:
Other		58	34	106	59
Total operating revenue	[1]	1,776	1,813	3,666	3,950
Dominion Gas Holdings, LLC
Gas sales:
Regulated		12	21	41	78
Nonregulated		6	1	7	4
Gas transportation and storage		301	321	652	733
NGL revenue		9	22	26	51
Other		40	30	73	60
Total operating revenue	[2]	$ 368	$ 395	$ 799	$ 926

[1] See Note 17 for amounts attributable to affiliates.

[2] See Note 17 for amounts attributable to related parties.

XML

Income Taxes (Reconciliation of Income Taxes at the U.S. Statutory Federal Rate as Compared to the Income Tax Expense Recorded in Our Consolidated Statements of Income) (Details)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating Loss Carryforwards [Line Items]
United States statutory rate	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.30%	3.30%
Investment tax credits	(9.90%)	(2.70%)
Production tax credits	(0.80%)	(0.80%)
State legislative change	(1.30%)	0.00%
Other, net	(2.30%)	(1.00%)
Effective tax rate	25.00%	33.80%
Virginia Electric and Power Company
Operating Loss Carryforwards [Line Items]
United States statutory rate	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	4.00%	3.80%
Investment tax credits	(0.00%)	(0.00%)
Production tax credits	(0.60%)	(0.50%)
State legislative change	0.00%	0.00%
Other, net	(0.50%)	(0.70%)
Effective tax rate	37.90%	37.60%
Dominion Gas Holdings, LLC
Operating Loss Carryforwards [Line Items]
United States statutory rate	35.00%	35.00%
Increases (reductions) resulting from:
State taxes, net of federal benefit	3.80%	3.90%
Investment tax credits	(0.00%)	(0.00%)
Production tax credits	(0.00%)	(0.00%)
State legislative change	0.00%	0.00%
Other, net	(0.10%)	0.00%
Effective tax rate	38.70%	38.90%

XML

Earnings Per Share (Calculation of Basic and Diluted EPS) (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Earnings Per Share [Abstract]
Net income attributable to Dominion		$ 452	$ 413	$ 976	$ 949
Average shares of common stock outstanding – Basic (shares)		615.6	591.5	606.1	589.7
Net effect of dilutive securities (shares)	[1]	1.4	1.0	1.5	1.5
Average shares of common stock outstanding – Diluted (shares)		617.0	592.5	607.6	591.2
Earnings Per Common Share – Basic		$ 0.73	$ 0.70	$ 1.61	$ 1.61
Earnings Per Common Share – Diluted		$ 0.73	$ 0.70	$ 1.61	$ 1.60

[1] Dilutive securities consist primarily of the 2013 Equity Units. See Note 14 in this report and Note 17 to the Consolidated Financial Statements in the Companies' Annual Report on Form 10-K for the year ended December 31, 2015 for more information.

XML

Accumulated Other Comprehensive Income (Schedule of Changes in AOCI by Component Net of Tax) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance	[1]			$ 13,602
Total other comprehensive income (loss)		$ (30)	$ 23	(19)	$ 30
Ending balance		15,452		15,452
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Total other comprehensive income (loss)		(8)	3	(16)	0
Total
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(463)	(409)	(474)	(416)
Other comprehensive income before reclassifications: gains (losses)		14	84	82	40
Amounts reclassified from AOCI: (gains) losses	[2]	(44)	(61)	(101)	(10)
Total other comprehensive income (loss)		(30)	23	(19)	30
Ending balance		(493)	(386)	(493)	(386)
Total | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(107)	(89)	(99)	(86)
Other comprehensive income before reclassifications: gains (losses)		(9)	3	(15)	(1)
Amounts reclassified from AOCI: (gains) losses	[2]	1	0	(1)	1
Total other comprehensive income (loss)		(8)	3	(16)	0
Ending balance		(115)	(86)	(115)	(86)
Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(186)	(177)	(176)	(178)
Other comprehensive income before reclassifications: gains (losses)		(11)	92	42	34
Amounts reclassified from AOCI: (gains) losses	[2]	(44)	(61)	(107)	(2)
Total other comprehensive income (loss)		(55)	31	(65)	32
Ending balance		(241)	(146)	(241)	(146)
Deferred Gains and Losses on Derivatives-Hedging Activities | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(25)	(24)	(17)	(20)
Other comprehensive income before reclassifications: gains (losses)		(9)	3	(15)	(1)
Amounts reclassified from AOCI: (gains) losses	[2]	0	(1)	(2)	(1)
Total other comprehensive income (loss)		(9)	2	(17)	(2)
Ending balance		(34)	(22)	(34)	(22)
Unrealized Gains and Losses on Investment Securities
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		517	542	504	548
Other comprehensive income before reclassifications: gains (losses)		26	(11)	41	4
Amounts reclassified from AOCI: (gains) losses	[2]	(8)	(12)	(10)	(33)
Total other comprehensive income (loss)		18	(23)	31	(29)
Ending balance		535	519	535	519
Unrecognized Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(789)	(769)	(797)	(782)
Other comprehensive income before reclassifications: gains (losses)		0	3	0	3
Amounts reclassified from AOCI: (gains) losses	[2]	8	12	16	25
Total other comprehensive income (loss)		8	15	16	28
Ending balance		(781)	(754)	(781)	(754)
Unrecognized Pension and Other Postretirement Benefit Costs | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(82)	(65)	(82)	(66)
Other comprehensive income before reclassifications: gains (losses)		0	0	0	0
Amounts reclassified from AOCI: (gains) losses	[2]	1	1	1	2
Total other comprehensive income (loss)		1	1	1	2
Ending balance		(81)	(64)	(81)	(64)
Other Comprehensive Income (Loss) From Equity Method Investee
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
Beginning balance		(5)	(5)	(5)	(4)
Other comprehensive income before reclassifications: gains (losses)		(1)	0	(1)	(1)
Amounts reclassified from AOCI: (gains) losses	[2]	0	0	0	0
Total other comprehensive income (loss)		(1)	0	(1)	(1)
Ending balance		$ (6)	$ (5)	$ (6)	$ (5)

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[2] See table below for details about these reclassifications.

XML

Accumulated Other Comprehensive Income (Schedule of Reclassifications out of AOCI by Component Net of Tax) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating revenue		$ (2,598)	$ (2,747)	$ (5,519)	$ (6,156)
Purchased gas		56	111	175	361
Electric fuel and other energy-related purchases		551	591	1,185	1,544
Interest and related charges		239	221	465	444
Other income		(72)	(56)	(126)	(116)
Income from operations including noncontrolling interests before income tax expense		(614)	(608)	(1,324)	(1,447)
Income tax expense		152	190	331	489
Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating revenue	[1]	(368)	(395)	(799)	(926)
Purchased gas	[1]	16	21	50	95
Interest and related charges		23	18	45	35
Other income		(9)	(4)	(15)	(13)
Income from operations including noncontrolling interests before income tax expense		(172)	(139)	(331)	(402)
Income tax expense		67	54	128	156
Deferred Gains and Losses on Derivatives-Hedging Activities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, net of tax	[2]	(44)	(61)	(107)	(2)
Deferred Gains and Losses on Derivatives-Hedging Activities | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, net of tax	[2]	0	(1)	(2)	(1)
Deferred Gains and Losses on Derivatives-Hedging Activities | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Income from operations including noncontrolling interests before income tax expense		(72)	(102)	(174)	(4)
Income tax expense		28	41	67	2
Income from continuing operations including noncontrolling interests		(44)	(61)	(107)	(2)
Deferred Gains and Losses on Derivatives-Hedging Activities | Amounts Reclassified From AOCI | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Income from operations including noncontrolling interests before income tax expense		2	(1)	(2)	(1)
Income tax expense		(2)	0	0	0
Income from continuing operations including noncontrolling interests		0	(1)	(2)	(1)
Deferred Gains and Losses on Derivatives-Hedging Activities | Commodity contracts | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating revenue		(87)	(107)	(201)	(15)
Purchased gas		2	2	8	7
Electric fuel and other energy-related purchases		3		6	1
Deferred Gains and Losses on Derivatives-Hedging Activities | Commodity contracts | Amounts Reclassified From AOCI | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Operating revenue			(1)	(4)	(1)
Deferred Gains and Losses on Derivatives-Hedging Activities | Foreign currency contracts | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Interest and related charges		8	3	11	5
Deferred Gains and Losses on Derivatives-Hedging Activities | Foreign currency | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other income		2		2
Deferred Gains and Losses on Derivatives-Hedging Activities | Foreign currency | Amounts Reclassified From AOCI | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other income		2		2
Unrealized Gains and Losses on Investment Securities
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, net of tax	[2]	(8)	(12)	(10)	(33)
Unrealized Gains and Losses on Investment Securities | Amounts Reclassified From AOCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Realized (gain) loss on sale of securities		(20)	(25)	(30)	(64)
Impairment		7	5	14	11
Income from operations including noncontrolling interests before income tax expense		(13)	(20)	(16)	(53)
Income tax expense		5	8	6	20
Income from continuing operations including noncontrolling interests		(8)	(12)	(10)	(33)
Unrecognized Pension and Other Postretirement Benefit Costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		14	21	28	43
Unrecognized pension and other postretirement benefit costs, income tax expense		(6)	(9)	(12)	(18)
Unrecognized pension and other postretirement benefit costs, net of tax	[2]	8	12	16	25
Unrecognized Pension and Other Postretirement Benefit Costs | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		1	2	2	4
Unrecognized pension and other postretirement benefit costs, income tax expense		0	(1)	(1)	(2)
Unrecognized pension and other postretirement benefit costs, net of tax	[2]	1	1	1	2
Prior service (credit) costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		(3)	(3)	(7)	(6)
Actuarial (gains) losses
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		17	24	35	49
Actuarial (gains) losses | Dominion Gas Holdings, LLC
Accumulated Other Comprehensive Income (Loss) [Line Items]
Unrecognized pension and other postretirement benefit costs, before tax		$ 1	$ 2	$ 2	$ 4

[1] See Note 17 for amounts attributable to related parties.

[2] See table below for details about these reclassifications.

XML

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Details) $ in Millions		6 Months Ended
		Jun. 30, 2016 USD ($) $ / MWh $ / MMBTU	Dec. 31, 2015 USD ($)
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 354	$ 388
Fair Value of Derivative Liabilities		473	343
Level 3
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		137
Fair Value of Derivative Liabilities		13
Level 3 | Natural Gas | Physical and financial forwards and futures:
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[1]	123
Fair Value of Derivative Liabilities	[1]	5
Level 3 | Natural Gas | Physical and financial options:
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		8
Fair Value of Derivative Liabilities		1
Level 3 | FTRs | Physical and financial forwards and futures:
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		6
Fair Value of Derivative Liabilities		$ 7
Level 3 | Liabilities | Natural Gas | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	(1)
Level 3 | Liabilities | Natural Gas | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	4
Level 3 | Liabilities | Natural Gas | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2],[3]	3
Level 3 | Liabilities | Natural Gas | Physical and financial options: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	2
Price Volatility (percentage)	[4]	29.00%
Level 3 | Liabilities | Natural Gas | Physical and financial options: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	4
Price Volatility (percentage)	[4]	42.00%
Level 3 | Liabilities | Natural Gas | Physical and financial options: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2],[3]	3
Price Volatility (percentage)	[3],[4]	36.00%
Level 3 | Liabilities | FTRs | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[2]	(2)
Level 3 | Liabilities | FTRs | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[2]	5
Level 3 | Liabilities | FTRs | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[2],[3]	1
Level 3 | Assets | Natural Gas | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	(2)
Credit spread (percentage)	[5]	1.00%
Level 3 | Assets | Natural Gas | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	7
Credit spread (percentage)	[5]	6.00%
Level 3 | Assets | Natural Gas | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2],[3]	0
Credit spread (percentage)	[3],[5]	3.00%
Level 3 | Assets | Natural Gas | Physical and financial options: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	2
Price Volatility (percentage)	[4]	20.00%
Level 3 | Assets | Natural Gas | Physical and financial options: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2]	7
Price Volatility (percentage)	[4]	42.00%
Level 3 | Assets | Natural Gas | Physical and financial options: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[2],[3]	4
Price Volatility (percentage)	[3],[4]	25.00%
Level 3 | Assets | FTRs | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[2]	(8)
Level 3 | Assets | FTRs | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[2]	3
Level 3 | Assets | FTRs | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[2],[3]	1
Virginia Electric and Power Company
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 163	127
Fair Value of Derivative Liabilities		274	86
Virginia Electric and Power Company | Level 3
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		132
Fair Value of Derivative Liabilities		7
Virginia Electric and Power Company | Level 3 | Natural Gas | Physical and financial forwards and futures:
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets	[6]	121
Virginia Electric and Power Company | Level 3 | Natural Gas | Physical and financial options:
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		5
Virginia Electric and Power Company | Level 3 | FTRs | Physical and financial forwards and futures:
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		6
Fair Value of Derivative Liabilities		$ 7
Virginia Electric and Power Company | Level 3 | Liabilities | Natural Gas | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[7]	(2)
Virginia Electric and Power Company | Level 3 | Liabilities | Natural Gas | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[7]	5
Virginia Electric and Power Company | Level 3 | Liabilities | FTRs | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[7],[8]	1
Virginia Electric and Power Company | Level 3 | Assets | Natural Gas | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[7]	(2)
Credit spread (percentage)	[9]	1.00%
Virginia Electric and Power Company | Level 3 | Assets | Natural Gas | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[7]	7
Credit spread (percentage)	[9]	6.00%
Virginia Electric and Power Company | Level 3 | Assets | Natural Gas | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[7],[8]	0
Credit spread (percentage)	[8],[9]	3.00%
Virginia Electric and Power Company | Level 3 | Assets | Natural Gas | Physical and financial options: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[7]	2
Price Volatility (percentage)	[10]	20.00%
Virginia Electric and Power Company | Level 3 | Assets | Natural Gas | Physical and financial options: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[7]	7
Price Volatility (percentage)	[10]	33.00%
Virginia Electric and Power Company | Level 3 | Assets | Natural Gas | Physical and financial options: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MMBTU	[7],[8]	4
Price Volatility (percentage)	[8],[10]	24.00%
Virginia Electric and Power Company | Level 3 | Assets | FTRs | Physical and financial forwards and futures: | Minimum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[7]	(8)
Virginia Electric and Power Company | Level 3 | Assets | FTRs | Physical and financial forwards and futures: | Maximum
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[7]	3
Virginia Electric and Power Company | Level 3 | Assets | FTRs | Physical and financial forwards and futures: | Wieghted Average
Fair Value, Option, Quantitative Disclosures [Line Items]
Market Price (per unit) | $ / MWh	[7],[8]	1
Dominion Gas Holdings, LLC
Fair Value, Option, Quantitative Disclosures [Line Items]
Fair Value of Derivative Assets		$ 3	11
Fair Value of Derivative Liabilities		$ 12	$ 14

[1] Includes basis.

[2] Represents market prices beyond defined terms for Levels 1 and 2.

[3] Averages weighted by volume.

[4] Represents volatilities unrepresented in published markets.

[5] Represents credit spreads unrepresented in published markets.

[6] Includes basis.

[7] Represents market prices beyond defined terms for Levels 1 and 2.

[8] Averages weighted by volume.

[9] Represents credit spreads unrepresented in published markets.

[10] Represents volatilities unrepresented in published markets.

XML

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		$ 354	$ 388
Derivative Liabilities		473	343
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		137
Derivative Liabilities		13
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[1]	4,735	4,589
Total liabilities		473	343
Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		329	364
Derivative Liabilities		100	160
Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		25	24
Derivative Liabilities		366	183
Fair Value, Measurements, Recurring | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		7
Fair Value, Measurements, Recurring | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	2,617	2,547
Fair Value, Measurements, Recurring | Equity securities: | Large cap | Non-United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	10	10
Fair Value, Measurements, Recurring | Equity securities: | Other | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5	5
Fair Value, Measurements, Recurring | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	72	63
Fair Value, Measurements, Recurring | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	498	437
Fair Value, Measurements, Recurring | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	698	659
Fair Value, Measurements, Recurring | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	364	376
Fair Value, Measurements, Recurring | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	112	100
Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5	4
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[1]	3,171	3,086
Total liabilities		0	0
Fair Value, Measurements, Recurring | Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	1
Derivative Liabilities		0	0
Fair Value, Measurements, Recurring | Level 1 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liabilities		0	0
Fair Value, Measurements, Recurring | Level 1 | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		0
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	2,617	2,547
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large cap | Non-United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	10	10
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5	5
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	72	63
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	462	458
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	5	2
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[1]	1,427	1,389
Total liabilities		460	324
Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		192	249
Derivative Liabilities		87	141
Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		25	24
Derivative Liabilities		366	183
Fair Value, Measurements, Recurring | Level 2 | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		7
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large cap | Non-United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	498	437
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	236	201
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	364	376
Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	112	100
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	2
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[1]	137	114
Total liabilities		13	19
Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		137	114
Derivative Liabilities		13	19
Fair Value, Measurements, Recurring | Level 3 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liabilities		0	0
Fair Value, Measurements, Recurring | Level 3 | Foreign currency
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities		0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large cap | Non-United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Fair Value, Measurements, Recurring | Level 3 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[1]	0	0
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		163	127
Derivative Liabilities		274	86
Virginia Electric and Power Company | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		132
Derivative Liabilities		7
Virginia Electric and Power Company | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	2,139	1,996
Total liabilities		274	86
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		163	114
Derivative Liabilities		17	27
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset			13
Derivative Liabilities		257	59
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	1,137	1,100
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	72	63
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	283	238
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	277	259
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	159	175
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	48
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		34
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	1,375	1,343
Total liabilities		0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liabilities		0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset			0
Derivative Liabilities		0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	1,137	1,100
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	72	63
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	166	180
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	632	552
Total liabilities		267	78
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		31	13
Derivative Liabilities		10	19
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset			13
Derivative Liabilities		257	59
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	283	238
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	111	79
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	159	175
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	48
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		34
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets	[2]	132	101
Total liabilities		7	8
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		132	101
Derivative Liabilities		7	8
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset			0
Derivative Liabilities		0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large cap | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | REIT | United States:
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Corporate debt instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | United States Treasury securities and agency debentures
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | State and municipal
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed income: | Other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]	0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Cash equivalents and other
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments	[2]		0
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		3	11
Derivative Liabilities		12	14
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		3	11
Total liabilities		12	14
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		3	11
Derivative Liabilities		5
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities			14
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		0	0
Total liabilities		0	0
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 1 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	0
Derivative Liabilities		0
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 1 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities			0
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		3	5
Total liabilities		12	14
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 2 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		3	5
Derivative Liabilities		5
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 2 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities			14
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total assets		0	6
Total liabilities		0	0
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 3 | Commodity
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset		0	6
Derivative Liabilities		$ 0
Dominion Gas Holdings, LLC | Fair Value, Measurements, Recurring | Level 3 | Interest rate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liabilities			$ 0

[1] Includes investments held in the nuclear decommissioning and rabbi trusts.

[2] Includes investments held in the nuclear decommissioning and rabbi trusts.

XML

Fair Value Measurements (Net Change in the Assets and Liabilities Measured at Fair Value on a Recurring Basis and Included in the Level 3 Fair Value Category) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Total realized and unrealized gains (losses):
Included in earnings	$ (10)	$ (5)	$ (17)	$ 10
Fair Value, Measurements, Recurring | Level 3 | Commodity Transactions
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	109	76	95	107
Total realized and unrealized gains (losses):
Included in earnings	(10)	(5)	(17)	10
Included in other comprehensive income (loss)	0	(1)	3	(12)
Included in regulatory assets/liabilities	15	(5)	32	(29)
Settlements	10	6	18	(8)
Transfers out of Level 3	0	0	(7)	3
Ending balance	124	71	124	71
Fair Value, Measurements, Recurring | Level 3 | Commodity Transactions | Virginia Electric and Power Company
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	110	78	93	102
Total realized and unrealized gains (losses):
Included in earnings	(9)	(5)	(17)	8
Included in regulatory assets/liabilities	15	(5)	32	(29)
Settlements	9	5	17	(8)
Ending balance	125	73	125	73
Fair Value, Measurements, Recurring | Level 3 | Commodity Transactions | Dominion Gas Holdings, LLC
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	0	0	6	2
Total realized and unrealized gains (losses):
Included in earnings	0	(1)	0	1
Included in other comprehensive income (loss)	0	0	2	(12)
Settlements	0	0	0	(1)
Transfers out of Level 3	0	0	(8)	9
Ending balance	$ 0	$ (1)	$ 0	$ (1)

XML

Fair Value Measurements (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains or losses included in earnings in Level 3 fair value category	$ 0	$ 0	$ 0	$ 0
Virginia Electric and Power Company
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains or losses included in earnings in Level 3 fair value category	0	0	0	0
Dominion Gas Holdings, LLC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains or losses included in earnings in Level 3 fair value category	$ 0	$ 0	$ 0	$ 0

XML

Fair Value Measurements (Gains and Losses Included in Earnings in the Level 3 Fair Value Category) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	$ (10)	$ (5)	$ (17)	$ 10
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date			0	0
Operating Revenue
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	0	0	0	2
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date			0	1
Electric Fuel and Other Energy-Related Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) included in earnings	$ (10)	$ (5)	(17)	8
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets/liabilities still held at the reporting date			$ 0	$ (1)

XML

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Details) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Junior subordinated notes		$ 2,399	$ 1,340	[1]
Valuation of certain fair value hedges		21	7
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	[2]	22,754	21,873
Junior subordinated notes	[3]	2,399	1,340
Remarketable subordinated notes	[3]	982	2,080
Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	[2],[4]	25,400	23,210
Junior subordinated notes	[3],[4]	2,310	1,192
Remarketable subordinated notes	[3],[4]	1,037	2,129
Virginia Electric and Power Company | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	[3]	9,661	9,368
Virginia Electric and Power Company | Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	[3],[4]	11,329	10,400
Dominion Gas Holdings, LLC | Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	[5]	3,941	3,269
Dominion Gas Holdings, LLC | Estimate of Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	[4],[5]	$ 4,116	$ 3,299

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[2] Carrying amount includes amounts which represent the unamortized debt issuance costs, discount and/or premium, and foreign currency remeasurement adjustments. At June 30, 2016 and December 31, 2015, includes the valuation of certain fair value hedges associated with fixed rate debt of $21 million and $7 million, respectively.

[3] Carrying amount includes amounts which represent the unamortized debt issuance costs, discount and/or premium.

[4] 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.

[5] Carrying amount includes amounts which represent the unamortized debt issuance costs, discount and/or premium, and foreign currency remeasurement adjustments.

XML

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 347	$ 379
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	347	379
Total derivatives, not subject to a master netting or similar arrangement	7	9
Gross Amounts of Recognized Assets, Total	354	388
Derivative Asset	354	388
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	94	141
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	253	238
Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	231	217
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	231	217
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	16	37
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	215	180
Commodity | Exchange
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	91	138
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	91	138
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	63	82
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	28	56
Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	25	24
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	25	24
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	15	22
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	10	2
Virginia Electric and Power Company
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	127	114
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	127	114
Total derivatives, not subject to a master netting or similar arrangement	36	13
Gross Amounts of Recognized Assets, Total	163	127
Derivative Asset	163	127
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	7	13
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	120	101
Virginia Electric and Power Company | Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	127	101
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	127	101
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	7	3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	120	98
Virginia Electric and Power Company | Interest rate | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	0	13
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	0	13
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	10
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	0	3
Dominion Gas Holdings, LLC
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	3	11
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	3	11
Derivative Asset	3	11
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	0	11
Dominion Gas Holdings, LLC | Commodity | Over-the-counter
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	3	11
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Assets Presented in the Consolidated Balance Sheet	3	11
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0	0
Net Amounts	$ 0	$ 11

XML

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 468	$ 335
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	468	335
Total derivatives, not subject to a master netting or similar arrangement	5	8
Gross Amounts of Recognized Liabilities, Total	473	343
Derivative Liabilities	473	343
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	94	141
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	1	0
Net Amounts	373	194
Foreign currency | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	7	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	7	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	7	0
Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	366	183
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	366	183
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	15	22
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	351	161
Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	32	70
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	32	70
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	16	37
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	1	0
Net Amounts	15	33
Commodity | Exchange
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	63	82
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	63	82
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	63	82
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	0	0
Virginia Electric and Power Company
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	271	64
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	271	64
Total derivatives, not subject to a master netting or similar arrangement	3	22
Gross Amounts of Recognized Liabilities, Total	274	86
Derivative Liabilities	274	86
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	7	13
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	1	0
Net Amounts	263	51
Virginia Electric and Power Company | Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	257	59
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	257	59
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	10
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	257	49
Virginia Electric and Power Company | Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	14	5
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	14	5
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	7	3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	1	0
Net Amounts	6	2
Dominion Gas Holdings, LLC
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	12	14
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	12	14
Derivative Liabilities	12	14
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	9	14
Dominion Gas Holdings, LLC | Foreign currency | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	7	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	7	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	7	0
Dominion Gas Holdings, LLC | Interest rate | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	0	14
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	0	14
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	0	14
Dominion Gas Holdings, LLC | Commodity | Over-the-counter
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	5	0
Gross Amounts Offset in the Consolidated Balance Sheet	0	0
Net Amounts of Liabilities Presented in the Consolidated Balance Sheet	5	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	3	0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral	0	0
Net Amounts	$ 2	$ 0

XML

Derivatives and Hedge Accounting Activities (Volume of Derivative Activity) (Details) - 6 months ended Jun. 30, 2016 MMcf in Thousands, € in Millions, $ in Millions		USD ($) MWh MMcf gal	EUR (€)
Fixed Price - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	[1]	125
Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	[1]	38
Basis - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		190
Basis - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		580
Fixed Price - Electricity - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh		11,749,639
Fixed Price - Electricity - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh		1,978,640
Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh		99,882,813
Financial Transmission Rights - Electricity- Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh		0
Liquids - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal	[2]	59,807,554
Liquids - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal	[2]	0
Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | €			€ 250
Foreign Exchange - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	[3],[4]	$ 0
Foreign Exchange - Non- Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	[3],[4]	280
Interest Rate - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	[4]	2,400
Interest Rate - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	[4]	$ 2,100
Virginia Electric and Power Company | Fixed Price - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	[5]	42
Virginia Electric and Power Company | Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)	[5]	16
Virginia Electric and Power Company | Basis - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		67
Virginia Electric and Power Company | Basis - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		538
Virginia Electric and Power Company | Financial Transmission Rights - Electricity- Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh		97,710,646
Virginia Electric and Power Company | Financial Transmission Rights - Electricity- Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of electricity (MWh) | MWh		0
Virginia Electric and Power Company | Interest Rate - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $		$ 700
Virginia Electric and Power Company | Interest Rate - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $		$ 1,100
Dominion Gas Holdings, LLC | Fixed Price - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		7
Dominion Gas Holdings, LLC | Fixed Price - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		0
Dominion Gas Holdings, LLC | Basis - Natural Gas - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		7
Dominion Gas Holdings, LLC | Basis - Natural Gas - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal)		0
Dominion Gas Holdings, LLC | Liquids - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal		52,247,554
Dominion Gas Holdings, LLC | Liquids - Non-current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative activity (bcf, Gal) | gal		0
Dominion Gas Holdings, LLC | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | €			€ 250
Dominion Gas Holdings, LLC | Foreign Exchange - Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	[6]	$ 0
Dominion Gas Holdings, LLC | Foreign Exchange - Non- Current Derivative Contract
Derivative Instruments, Gain (Loss) [Line Items]
Interest rate | $	[6]	$ 280

[1] Includes options.

[2] Includes NGLs and oil.

[3] Euro equivalent volumes are €250,000,000.

[4] Maturity is determined based on final settlement period.

[5] Includes options.

[6] Maturity is determined based on final settlement period. Euro equivalent volumes are €250,000,000.

XML

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (241)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	47
Commodity | Gas Energy Contract
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	10
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 9
Maximum Term	22 months
Commodity | Electricity Energy Contract
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ 65
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ 65
Maximum Term	18 months
Commodity | Other Energy Contract
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (1)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (1)
Maximum Term	9 months
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (312)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (23)
Maximum Term	381 months
Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (3)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (3)
Maximum Term	120 months
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (21)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(1)
Virginia Electric and Power Company | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	(21)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (1)
Maximum Term	381 months
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (34)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	(8)
Dominion Gas Holdings, LLC | Commodity | NGLs
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	(1)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (1)
Maximum Term	9 months
Dominion Gas Holdings, LLC | Interest rate | NGLs
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (30)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (4)
Maximum Term	342 months
Dominion Gas Holdings, LLC | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
AOCI After-Tax	$ (3)
Amounts Expected to be Reclassified to Earnings During the Next 12 Months After-Tax	$ (3)
Maximum Term	120 months

XML

Derivatives and Hedge Accounting Activities (Fair Value of Derivatives) (Details) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		$ 354	$ 388
Derivative Liabilities		473	343
Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[1]	192	255
Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		188	252
Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		4	3
Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[2]	162	133
Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		141	112
Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		21	21
Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[3]	271	312
Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		88	148
Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		178	164
Current Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5
Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[4]	202	31
Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		12	12
Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		188	19
Noncurrent Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		2
Fair Value – Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		98	128
Derivative Liabilities		405	215
Fair Value – Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[1]	71	104
Fair Value – Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		67	101
Fair Value – Derivatives under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		4	3
Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[2]	27	24
Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		6	3
Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		21	21
Fair Value – Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[3]	210	196
Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		27	32
Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		178	164
Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5
Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[4]	195	19
Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5	0
Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		188	19
Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		2
Fair Value – Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		256	260
Derivative Liabilities		68	128
Fair Value – Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[1]	121	151
Fair Value – Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		121	151
Fair Value – Derivatives not under Hedge Accounting | Current Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		0	0
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[2]	135	109
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		135	109
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		0	0
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[3]	61	116
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		61	116
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0	0
Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[4]	7	12
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		7	12
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0	0
Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		163	127
Derivative Liabilities		274	86
Virginia Electric and Power Company | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[5]	34	18
Virginia Electric and Power Company | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		34	18
Virginia Electric and Power Company | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[6]	129	109
Virginia Electric and Power Company | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		129	96
Virginia Electric and Power Company | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset			13
Virginia Electric and Power Company | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[7]	81	80
Virginia Electric and Power Company | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		12	23
Virginia Electric and Power Company | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		69	57
Virginia Electric and Power Company | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[8]	193	6
Virginia Electric and Power Company | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5	4
Virginia Electric and Power Company | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		188	2
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		0	13
Derivative Liabilities		257	59
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[5]	0	0
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		0	0
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[6]	0	13
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		0	0
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset			13
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[7]	69	57
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0	0
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		69	57
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[8]	188	2
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0	0
Virginia Electric and Power Company | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		188	2
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		163	114
Derivative Liabilities		17	27
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[5]	34	18
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		34	18
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[6]	129	96
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		129	96
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset			0
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[7]	12	23
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		12	23
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0	0
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[8]	5	4
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5	4
Virginia Electric and Power Company | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0	0
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		3	11
Derivative Liabilities		12	14
Dominion Gas Holdings, LLC | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[9]	3	10
Dominion Gas Holdings, LLC | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		3	10
Dominion Gas Holdings, LLC | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[10]		1
Dominion Gas Holdings, LLC | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset			1
Dominion Gas Holdings, LLC | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[11]	10
Dominion Gas Holdings, LLC | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5
Dominion Gas Holdings, LLC | Current Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5
Dominion Gas Holdings, LLC | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[12]	2	14
Dominion Gas Holdings, LLC | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities			14
Dominion Gas Holdings, LLC | Noncurrent Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		2
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		2	11
Derivative Liabilities		11	14
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[9]	2	10
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		2	10
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[10]		1
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset			1
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[11]	9
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		4
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Current Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		5
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[12]	2	14
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities			14
Dominion Gas Holdings, LLC | Fair Value – Derivatives under Hedge Accounting | Noncurrent Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		2
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		1	0
Derivative Liabilities		1	0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Current Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[9]	1	0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Current Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset		1	0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset	[10]		0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Asset			0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[11]	1
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		1
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Current Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities	[12]	0	0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities			$ 0
Dominion Gas Holdings, LLC | Fair Value – Derivatives not under Hedge Accounting | Noncurrent Liabilities | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Liabilities		$ 0

[1] Current derivative assets are presented in other current assets in Dominion’s Consolidated Balance Sheets.

[2] Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheets.

[3] Current derivative liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.

[4] Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheets.

[5] Current derivative assets are presented in other current assets in Virginia Power's Consolidated Balance Sheets.

[6] Noncurrent derivative assets are presented in other deferred charges and other assets in Virginia Power's Consolidated Balance Sheets.

[7] Current derivative liabilities are presented in other current liabilities in Virginia Power's Consolidated Balance Sheets.

[8] Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheets.

[9] Current derivative assets are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.

[10] Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion Gas’ Consolidated Balance Sheets.

[11] Current derivative liabilities are presented in other current liabilities in Dominion Gas' Consolidated Balance Sheets.

[12] Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion Gas’ Consolidated Balance Sheets.

XML

Derivatives and Hedge Accounting Activities (Gains and Losses on Derivatives in Cash Flow Hedging Relationships) (Details) - Cash Flow Hedges - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016		Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	$ (18)	$ 151	$ 68		$ 53
Amount of Gain (Loss) Reclassified From AOCI to Income		72	102	174		4
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	(108)	(91)	(241)		45
Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1]	12	94	185		54
Amount of Gain (Loss) Reclassified From AOCI to Income		82	105	187		9
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2]	0	0	0		3
Commodity | Operating revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		87	107	201		15
Commodity | Purchased Gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(2)	(2)	(8)		(7)
Commodity | Electric Fuel and Other Energy-Related Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income		(3)		(6)		1
Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1],[3]	(7)		(7)
Amount of Gain (Loss) Reclassified From AOCI to Income	[3]	(2)		(2)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2],[3]	0		0
Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[1],[4]	(23)	57	(110)		(1)
Amount of Gain (Loss) Reclassified From AOCI to Income	[4]	(8)	(3)	(11)		(5)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[2],[4]	(108)	(91)	(241)		42
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5]	(10)	11	(24)		5
Amount of Gain (Loss) Reclassified From AOCI to Income		0	0	(1)		(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[6]	(108)	91	(241)		45
Virginia Electric and Power Company | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5]					0
Amount of Gain (Loss) Reclassified From AOCI to Income						(1)
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[6]					3
Virginia Electric and Power Company | Commodity | Electric Fuel and Other Energy-Related Purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income						(1)
Virginia Electric and Power Company | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[5],[7]	(10)	11	(24)		5
Amount of Gain (Loss) Reclassified From AOCI to Income	[7]	0	0	(1)		0
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	[6],[7]	(108)	91	(241)		42
Dominion Gas Holdings, LLC
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[8]	(13)	4	(23)		(2)
Amount of Gain (Loss) Reclassified From AOCI to Income		(2)	1	2		1
Dominion Gas Holdings, LLC | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[8]	(6)	0	(7)		(2)
Amount of Gain (Loss) Reclassified From AOCI to Income		0	1	4		1
Dominion Gas Holdings, LLC | Commodity | Operating revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Reclassified From AOCI to Income			1	4		$ 1
Dominion Gas Holdings, LLC | Foreign currency
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[8]	(7)		(7)	[9]
Amount of Gain (Loss) Reclassified From AOCI to Income		$ (2)		(2)	[9]
Dominion Gas Holdings, LLC | Interest rate
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	[8],[10]		4	(9)
Amount of Gain (Loss) Reclassified From AOCI to Income	[10]		$ 0	$ 0

[1] Amounts deferred into AOCI have no associated effect in Dominion’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’s Consolidated Statements of Income.

[3] Amounts recorded in Dominion’s Consolidated Statements of Income are classified in other income.

[4] Amounts recorded in Dominion’s Consolidated Statements of Income are classified in interest and related charges.

[5] Amounts deferred into AOCI have no associated effect in Virginia Power’s Consolidated Statements of Income.

[6] 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.

[7] Amounts recorded in Virginia Power’s Consolidated Statements of Income are classified in interest and related charges.

[8] Amounts deferred into AOCI have no associated effect in Dominion Gas' Consolidated Statements of Income.

[9] Amounts recorded in Dominion Gas' Consolidated Statements of Income are classified in other income.

[10] Amounts recorded in Dominion Gas' Consolidated Statements of Income are classified in interest and related charges.

XML

Derivatives and Hedge Accounting Activities (Schedule of Derivatives not Designated as Hedging Instruments) (Details) - Derivatives Not Designated as Hedging Instruments - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	$ (8)	$ 11	$ (30)	$ 18
Commodity | Operating revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(8)	15	(6)	18
Commodity | Purchased gas
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	8	(7)	7	(9)
Commodity | Electric fuel and other energy-related purchases
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	(9)	3	(31)	9
Commodity | Other operations and maintenance
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[1]	1	0	0	0
Virginia Electric and Power Company
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2]	(10)	5	(30)	12
Virginia Electric and Power Company | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives	[2],[3]	(10)	5	(30)	12
Dominion Gas Holdings, LLC | Commodity
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		(2)	3	(2)	4
Dominion Gas Holdings, LLC | Commodity | Operating revenue
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in Income on Derivatives		$ (2)	$ 3	$ (2)	$ 4

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

[2] 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.

[3] Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.

XML

Investments (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	May 31, 2016	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Gain (Loss) on Investments [Line Items]
Investment in equity method affiliates		$ 1,372		$ 1,320	[1]
Dominion Gas Holdings, LLC | Iroquois | Partnership Interest
Gain (Loss) on Investments [Line Items]
Equity in earnings on investments		9	$ 12
Distributions received from investment		11	$ 12
Investment in equity method affiliates		98		102
Carrying amount of investment that exceeded share of underlying equity		8		8
Percentage of non-controlling interests sold	0.65%
Sales price	$ 7
Gain on sale of interests	5
After tax gain on sale of interests	$ 3
Categories of Investments, Marketable Securities, Trading Securities
Gain (Loss) on Investments [Line Items]
Assets Held-in-trust		$ 104		$ 100

[1] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

XML

Investments (Marketable Equity and Debt Securities and Cash Equivalents (Classified as Available-for-sale) and Cost Method Investments in Decommissioning Trust Funds) (Details) - USD ($) $ in Millions		Jun. 30, 2016	Dec. 31, 2015
Investment Holdings [Line Items]
Amortized Cost, Total		$ 2,988	$ 2,936
Total Unrealized Gains	[1]	1,344	1,258
Total Unrealized Losses	[1],[2]	(1)	(11)
Fair Value		4,331	4,183	[3]
Net assets related to pending sales and purchases of securities		(16)	12
Fair value of securities in an unrealized loss position		90	592
Cost method investments
Investment Holdings [Line Items]
Amortized Cost, Other Investments		69	70
Total Unrealized Gains	[1]	0	0
Total Unrealized Losses	[1]	0	0
Fair Value		69	70
Cash equivalents and other
Investment Holdings [Line Items]
Amortized Cost, Other Investments	[4]	(12)	14
Total Unrealized Gains	[1],[4]	0	0
Total Unrealized Losses	[1],[4]	0	0
Fair Value	[4]	(12)	14
Equity securities | Large cap | United States:
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		1,326	1,295
Total Unrealized Gains	[1]	1,251	1,213
Total Unrealized Losses	[1]	0	0
Fair Value		2,577	2,508
Equity securities | REIT
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		61	59
Total Unrealized Gains	[1]	11	4
Total Unrealized Losses	[1]	0	0
Fair Value		72	63
Corporate bonds
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		474	433
Total Unrealized Gains	[1]	25	11
Total Unrealized Losses	[1]	(1)	(7)
Fair Value		498	437
United States Treasury securities and agency debentures
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		672	654
Total Unrealized Gains	[1]	26	8
Total Unrealized Losses	[1]	0	(4)
Fair Value		698	658
State and municipal
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		290	312
Total Unrealized Gains	[1]	31	22
Total Unrealized Losses	[1]	0	0
Fair Value		321	334
Other
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		108	99
Total Unrealized Gains	[1]	0	0
Total Unrealized Losses	[1]	0	0
Fair Value		108	99
Virginia Electric and Power Company
Investment Holdings [Line Items]
Amortized Cost, Total		1,437	1,404
Total Unrealized Gains	[5]	594	548
Total Unrealized Losses	[5],[6]	(1)	(7)
Fair Value		2,030	1,945	[7]
Net assets related to pending sales and purchases of securities		(13)	8
Fair value of securities in an unrealized loss position		66	281
Virginia Electric and Power Company | Cost method investments
Investment Holdings [Line Items]
Amortized Cost, Other Investments		69	70
Total Unrealized Gains	[5]	0	0
Total Unrealized Losses	[5]	0	0
Fair Value		69	70
Virginia Electric and Power Company | Cash equivalents and other
Investment Holdings [Line Items]
Amortized Cost, Other Investments	[8]	(13)	8
Total Unrealized Gains	[5],[8]	0	0
Total Unrealized Losses	[5],[8]	0	0
Fair Value	[8]	(13)	8
Virginia Electric and Power Company | Equity securities | Large cap | United States:
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		590	574
Total Unrealized Gains	[5]	546	525
Total Unrealized Losses	[5]	0	0
Fair Value		1,136	1,099
Virginia Electric and Power Company | Equity securities | REIT
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		61	59
Total Unrealized Gains	[5]	11	4
Total Unrealized Losses	[5]	0	0
Fair Value		72	63
Virginia Electric and Power Company | Corporate bonds
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		271	237
Total Unrealized Gains	[5]	13	5
Total Unrealized Losses	[5]	(1)	(4)
Fair Value		283	238
Virginia Electric and Power Company | United States Treasury securities and agency debentures
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		270	260
Total Unrealized Gains	[5]	7	1
Total Unrealized Losses	[5]	0	(2)
Fair Value		277	259
Virginia Electric and Power Company | State and municipal
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		141	162
Total Unrealized Gains	[5]	17	13
Total Unrealized Losses	[5]	0	(1)
Fair Value		158	174
Virginia Electric and Power Company | Other
Investment Holdings [Line Items]
Amortized Cost, Marketable Securities		48	34
Total Unrealized Gains	[5]	0	0
Total Unrealized Losses	[5]	0	0
Fair Value		$ 48	$ 34

[1] Included in AOCI and the nuclear decommissioning trust regulatory liability.

[2] The fair value of securities in an unrealized loss position was $90 million and $592 million at June 30, 2016 and December 31, 2015, respectively.

[3] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[4] Includes pending purchases of securities of $16 million and pending sales of securities of $12 million at June 30, 2016 and December 31, 2015, respectively.

[5] Included in AOCI and the nuclear decommissioning trust regulatory liability.

[6] The fair value of securities in an unrealized loss position was $66 million and $281 million at June 30, 2016 and December 31, 2015, respectively.

[7] Virginia Power’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[8] Includes pending purchases of securities of $13 million and pending sales of securities of $8 million at June 30, 2016 and December 31, 2015, respectively.

XML

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Details) $ in Millions	Jun. 30, 2016 USD ($)
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	$ 212
Due after one year through five years	458
Due after five years through ten years	390
Due after ten years	565
Total	1,625
Virginia Electric and Power Company
Schedule of Held-to-maturity Securities [Line Items]
Due in one year or less	71
Due after one year through five years	207
Due after five years through ten years	218
Due after ten years	270
Total	$ 766

XML

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Available-for-sale securities:
Proceeds from sales		$ 341	$ 243	$ 709	$ 580
Realized gains	[1]	37	44	62	100
Realized losses	[1]	15	12	34	29
Virginia Electric and Power Company
Available-for-sale securities:
Proceeds from sales		154	76	347	209
Realized gains	[2]	18	19	30	37
Realized losses	[2]	$ 7	$ 4	$ 17	$ 15

[1] Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.

[2] Includes realized gains and losses recorded to the nuclear decommissioning trust regulatory liability.

XML

Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions		6 Months Ended
		Jun. 30, 2016	Dec. 31, 2015
Regulatory Assets and Liablities [Line Items]
Deferred rate adjustment clause costs	[1]	$ 95	$ 90
Deferred cost of fuel used in electric generation	[2]	5	111
Deferred nuclear refueling outage costs	[3]	61	75
Other		60	75
Regulatory assets current	[4]	221	351
Unrecognized pension and other postretirement benefit costs	[5]	992	1,015
Deferred rate adjustment clause costs	[1]	342	295
Derivatives	[6]	351	110
PJM transmission rates	[7]	192	192
Income taxes recoverable through future rates	[8]	137	126
Other		136	127
Regulatory assets-non-current		2,150	1,865	[9]
Total regulatory assets		2,371	2,216
Deferred cost of fuel used in electric generation	[3]	89	0
PIPP	[10]	25	46
Other		47	54
Regulatory liabilities current	[11]	161	100
Provision for future cost of removal and AROs	[12]	1,148	1,120
Nuclear decommissioning trust	[13]	852	804
Deferred cost of fuel used in electric generation	[3]	26	97
Derivatives	[6]	108	79
Other		184	185
Regulatory liabilities-non-current		2,318	2,285	[9]
Total regulatory liabilities		$ 2,479	2,385
Amortization period for deferred costs		18 months
Virginia Electric and Power Company
Regulatory Assets and Liablities [Line Items]
Deferred rate adjustment clause costs	[1]	$ 72	80
Deferred cost of fuel used in electric generation	[3]	5	111
Deferred nuclear refueling outage costs	[2]	61	75
Other		55	60
Regulatory assets current		193	326	[14]
Deferred rate adjustment clause costs	[1]	254	213
Derivatives	[6]	351	110
PJM transmission rates	[7]	192	192
Income taxes recoverable through future rates	[8]	106	97
Other		63	55
Regulatory assets-non-current		966	667	[14]
Total regulatory assets		1,159	993
Deferred cost of fuel used in electric generation	[3]	89	0
Other		23	35
Regulatory liabilities current	[11]	112	35	[14]
Nuclear decommissioning trust	[13]	852	804
Deferred cost of fuel used in electric generation	[3]	26	97
Derivatives	[6]	108	79
Provision for future cost of removal	[12]	913	890
Other		57	59
Regulatory liabilities-non-current		1,956	1,929	[14]
Total regulatory liabilities		2,068	1,964
Dominion Gas Holdings, LLC
Regulatory Assets and Liablities [Line Items]
Deferred rate adjustment clause costs	[1]	23	10
Other		2	13
Regulatory assets current	[4]	25	23
Unrecognized pension and other postretirement benefit costs	[5]	277	282
Deferred rate adjustment clause costs	[1]	88	82
Income taxes recoverable through future rates	[8]	20	20
Other		66	65
Regulatory assets-non-current	[15]	451	449
Total regulatory assets		476	472
PIPP	[10]	25	46
Other		18	9
Regulatory liabilities current	[11]	43	55
Provision for future cost of removal and AROs	[12]	174	170
Other		39	31
Regulatory liabilities-non-current	[16]	213	201
Total regulatory liabilities		$ 256	$ 256

[1] Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects for Virginia Power. Reflects deferrals of costs associated with certain current and prospective rider projects for Dominion Gas. See Note 12 for more information.

[2] 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.

[3] Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Dominion's and Virginia Power's generation operations. See Note 12 for more information.

[4] Current regulatory assets are presented in other current assets in Dominion's and Dominion Gas' Consolidated Balance Sheets

[5] Represents unrecognized pension and other postretirement employee benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's and Dominion Gas' rate-regulated subsidiaries

[6] 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

[7] Reflects amounts related to PJM transmission cost allocation matter. See Note 12 for more information.

[8] Amounts to be recovered through future rates to pay income taxes that become payable when rate revenue is provided to recover AFUDC-equity and depreciation of property, plant and equipment for which deferred income taxes were not recognized for ratemaking purposes, including amounts attributable to tax rate changes

[9] Dominion’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[10] 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.

[11] Current regulatory liabilities are presented in other current liabilities in the Companies' Consolidated Balance Sheets

[12] 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.

[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] Virginia Power’s Consolidated Balance Sheet at December 31, 2015 has been derived from the audited Consolidated Financial Statements at that date.

[15] Noncurrent regulatory assets are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets

[16] Noncurrent regulatory liabilities are presented in other deferred credits and other liabilities in Dominion Gas' Consolidated Balance Sheets.

XML

Regulatory Assets and Liabilities (Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Public Utilities, General Disclosures [Line Items]
Regulatory assets past expenditures not earning return	$ 293
Period for which expenditures are expected to be recovered	2 years
Virginia Electric and Power Company
Public Utilities, General Disclosures [Line Items]
Regulatory assets past expenditures not earning return	$ 272
Dominion Gas Holdings, LLC
Public Utilities, General Disclosures [Line Items]
Regulatory assets past expenditures not earning return	$ 18

XML

Regulatory Matters (Narrative) (Details) $ in Millions		1 Months Ended							6 Months Ended	12 Months Ended
	Jul. 31, 2016 USD ($)	Aug. 31, 2016 USD ($) MW	Jun. 30, 2016 USD ($)	May 31, 2016 USD ($)	Oct. 31, 2015 USD ($) MW	Aug. 31, 2009 kV	Apr. 30, 2008	Apr. 30, 2007 kV	Jun. 30, 2016 USD ($) power_station	Dec. 31, 2015 USD ($)
Regulatory Matters [Line Items]
Regulatory asset			$ 2,371						$ 2,371	$ 2,216
Virginia Electric and Power Company
Regulatory Matters [Line Items]
ROE (percentage)							11.40%
Facility operating capacity (kV) | kV						500		500
Regulatory asset			1,159						1,159	993
Virginia Electric and Power Company | FERC Gas Regulation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | Settled Litigation
Regulatory Matters [Line Items]
Amount required to pay under settlement agreement			$ 200
Duration of payment under settlement agreement			10 years
Virginia Electric and Power Company | FERC Gas Regulation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | Settled Litigation | Regulatory asset recovered through retail rates
Regulatory Matters [Line Items]
Regulatory asset			$ 192						192
Virginia Electric and Power Company | FERC Gas Regulation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | Settled Litigation | Other operations and maintenance | Regulatory asset recovered through retail rates
Regulatory Matters [Line Items]
Remaining amount recorded in other operations and maintenance expense										$ 8
Virginia Electric and Power Company | FERC Gas Regulation | Order Regarding Transmission Rate Design for Allocation of Costs among PJM Interconnect LLC Transmission Customers | Unfavorable Regulatory Action | Settled Litigation | Other deferred credits and other liabilities
Regulatory Matters [Line Items]
Amount of contingent liability			200						$ 200
Virginia Electric and Power Company | Virginia Regulation
Regulatory Matters [Line Items]
Amount of fuel revenue decrease				$ 286
Virginia Electric and Power Company | Virginia Regulation | Rider S
Regulatory Matters [Line Items]
Proposed revenue requirement			254
Revenue requirement increase (decrease)			3
Virginia Electric and Power Company | Virginia Regulation | Rider R
Regulatory Matters [Line Items]
Proposed revenue requirement			75
Revenue requirement increase (decrease)			1
Virginia Electric and Power Company | Virginia Regulation | Rider W
Regulatory Matters [Line Items]
Proposed revenue requirement			126
Revenue requirement increase (decrease)			9
Virginia Electric and Power Company | Virginia Regulation | Rider B
Regulatory Matters [Line Items]
Proposed revenue requirement			28
Revenue requirement increase (decrease)			(1)
Number of power stations converted to biomass | power_station									3
Virginia Electric and Power Company | Virginia Regulation | Rider GV
Regulatory Matters [Line Items]
Proposed revenue requirement			89
Revenue requirement increase (decrease)			$ 49
Virginia Electric and Power Company | Virginia Regulation | Rider BW
Regulatory Matters [Line Items]
ROE (percentage)			10.60%
Approved revenue required			$ 119
Virginia Electric and Power Company | Virginia Regulation | Rider T1
Regulatory Matters [Line Items]
Proposed revenue requirement				639
Revenue requirement increase (decrease)				1
Virginia Electric and Power Company | Virginia Regulation | Solar Development Project | Subsequent Event | Scenario, Forecast
Regulatory Matters [Line Items]
Capacity of solar facility (mw) | MW		18
Total estimated cost		$ 40
Virginia Electric and Power Company | Virginia Regulation | Solar Development Project | Rider US-2
Regulatory Matters [Line Items]
ROE (percentage)			9.60%
Capacity of solar facility (mw) | MW					56
Total estimated cost					$ 130
Approved revenue required			$ 4
East Ohio | Ohio Regulation | UEX Rider
Regulatory Matters [Line Items]
Refund of accumulated bad debt expense				8
Net bad debt expense				19
East Ohio | Ohio Regulation | Subsequent Event | PIPP Plus Program
Regulatory Matters [Line Items]
Projected deferred program costs	$ 32
Refund of over-recovery of accumulated arrearages	$ 28
Hope Gas Inc | West Virginia Regulation | PREP
Regulatory Matters [Line Items]
Projected capital investment				$ 27
Period for capital investment				5 years
Total projected capital investment				$ 152
DCG | FERC Gas Regulation | Columbia to Eastover Project
Regulatory Matters [Line Items]
Amount of project			$ 45

XML

Variable Interest Entities (Narrative) (Details) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016 USD ($)	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) MW generator	Jun. 30, 2015 USD ($)	Dec. 31, 2015 generator
Dominion Midstream Partners, LP
Variable Interest Entities [Line Items]
Ownership interest percentage of limited partner interests			64.80%
Variable Interest Entity, Primary Beneficiary | Partnership Interest | Merchant Solar Projects
Variable Interest Entities [Line Items]
Ownership percentage			67.00%
Variable Interest Entity, Primary Beneficiary | Dominion Midstream Partners, LP | Partnership Interest
Variable Interest Entities [Line Items]
Ownership interest percentage of limited partner interests			64.80%
Variable Interest Entity, Not Primary Beneficiary | Jointly Owned Natural Gas Pipeline | Atlantic Coast Pipeline | Pipelines | Gas Distribution
Variable Interest Entities [Line Items]
Ownership percentage			45.00%
Variable Interest Entity, Not Primary Beneficiary | Virginia Electric and Power Company
Variable Interest Entities [Line Items]
Long term capacity contract non utility generators (generators) | generator			3		5
Number of expired non-utility generators | generator					2
Aggregate generation capacity from long-term power and capacity contracts (MW) | MW			418
Remaining purchase commitments			$ 357
Payment for electric capacity	$ 37	$ 55	74	$ 108
Payment for electric energy	5	23	12	60
Shared services purchased	74	83	$ 188	166
Variable Interest Entity, Not Primary Beneficiary | Virginia Electric and Power Company | Minimum
Variable Interest Entities [Line Items]
Contracts expiry date start range			2017
Variable Interest Entity, Not Primary Beneficiary | Virginia Electric and Power Company | Maximum
Variable Interest Entities [Line Items]
Contracts expiry date start range			2021
Variable Interest Entity, Not Primary Beneficiary | Dominion Gas Holdings, LLC
Variable Interest Entities [Line Items]
Shared services purchased	$ 29	$ 30	$ 64	$ 58

XML

Significant Financing Transactions (Narrative) (Details) € in Millions				1 Months Ended			6 Months Ended
	Jul. 01, 2016 shares	Apr. 01, 2016 shares	Jan. 31, 2016 USD ($)	Jul. 31, 2016 USD ($) shares	Apr. 30, 2016 USD ($) shares	Dec. 31, 2014 USD ($) agreement	Jun. 30, 2016 USD ($) facility	Jun. 30, 2015 USD ($)	Jun. 30, 2016 EUR (€) facility	May 31, 2016 USD ($)	Mar. 31, 2016 USD ($)
Debt Instrument [Line Items]
Issuance of common stock							$ 1,458,000,000	$ 647,000,000
Questar Corporation
Debt Instrument [Line Items]
Liabilities incurred			$ 3,900,000,000		$ 3,140,000,000
Shelf Registration for Sale of Common Stock through At-the-market Program
Debt Instrument [Line Items]
Number of sales agency agreements | agreement						4
Aggregate amount of common stock in which the company may offer under SEC shelf registration (up to $500 million)						$ 500,000,000
Common stock reserved for issuance in connection with stock purchase contracts								$ 200,000,000
Underwritten Public Offering
Debt Instrument [Line Items]
Number of common units issued | shares					10,200,000
Issuance of common stock					$ 756,000,000
Remarketable Subordinated Notes | 2013 Series A RSNs
Debt Instrument [Line Items]
Amount of debt											$ 550,000,000
Interest rate percentage											1.07%
Number of shares issued | shares		8,500,000.0			8,500,000.0
Remarketable Subordinated Notes | 2013 Series A RSNs | Subsequent Event
Debt Instrument [Line Items]
Number of shares issued | shares	8,500,000.0			8,500,000.0
Remarketable Subordinated Notes | 2013 Series B RSNs
Debt Instrument [Line Items]
Amount of debt										$ 550,000,000
Interest rate percentage										1.18%
Series A Junior Subordinated Notes | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Interest rate percentage											4.104%
Series B Junior Subordinated Notes | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Interest rate percentage										2.962%
June 2006 and September 2006 hybrids | Enhanced Junior Subordinated Notes | Subsequent Event
Debt Instrument [Line Items]
Amount purchased and cancelled				$ 200,000,000
June 2006 hybrids | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Amount purchased and cancelled											$ 38,000,000
June 2006 hybrids | Enhanced Junior Subordinated Notes | Subsequent Event
Debt Instrument [Line Items]
Amount purchased and cancelled				125,000,000
September 2006 hybrids | Enhanced Junior Subordinated Notes
Debt Instrument [Line Items]
Amount purchased and cancelled											$ 4,000,000
September 2006 hybrids | Enhanced Junior Subordinated Notes | Subsequent Event
Debt Instrument [Line Items]
Amount purchased and cancelled				74,000,000
July 2016 Hybrids | Enhanced Junior Subordinated Notes | Subsequent Event
Debt Instrument [Line Items]
Amount of debt				$ 800,000,000
Interest rate percentage				5.25%
Virginia Electric and Power Company
Debt Instrument [Line Items]
Number of joint revolving credit facilities | facility							2		2
Credit facility							$ 120,000,000
Virginia Electric and Power Company | Tax Exempt Debt
Debt Instrument [Line Items]
Variable rate tax-exempt financings							$ 119,000,000
Dominion Gas Holdings, LLC
Debt Instrument [Line Items]
Number of joint revolving credit facilities | facility							2		2
Dominion Gas Holdings, LLC | Senior Notes Due in 2031 | Senior Notes
Debt Instrument [Line Items]
Amount of debt										$ 150,000,000
Interest rate percentage										3.80%
Dominion Gas Holdings, LLC | Senior Notes Due in 2023 | Senior Notes
Debt Instrument [Line Items]
Amount of debt							$ 250,000,000
Interest rate percentage							2.875%		2.875%
Dominion Gas Holdings, LLC | Senior Notes Due in 2026 | Senior Notes
Debt Instrument [Line Items]
Amount of debt | €									€ 250
Interest rate percentage							1.45%		1.45%
Dominion Gas Holdings, LLC | Senior Notes Due in 2026 | Senior Notes | Long-term Debt
Debt Instrument [Line Items]
Amount of debt							$ 280,000,000
Amount of senior notes at period end							$ 278,000,000

XML

Significant Financing Transactions (Commercial Paper, Bank Loans and Letters of Credit Outstanding) (Details)	Jun. 30, 2016 USD ($)
Line of Credit Facility [Line Items]
Facility Limit	$ 5,500,000,000
Outstanding Commercial Paper	3,437,000,000
Outstanding Letters of Credit	52,000,000
Facility Capacity Available	2,011,000,000
Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	5,500,000,000	[1]
Outstanding Commercial Paper	1,423,000,000
Outstanding Letters of Credit	0
Dominion Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	1,500,000,000	[2]
Outstanding Commercial Paper	238,000,000
Outstanding Letters of Credit	0
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000.0
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Dominion Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	1,500,000,000.0
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Line of Credit | Dominion Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	1,000,000,000.0
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Letter of Credit
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000.0
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Letter of Credit | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	2,000,000,000.0
Joint Revolving Credit Facility 4 Billion and Joint Revolving Credit Facility 500 Million | Letter of Credit | Dominion Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	1,500,000,000.0
Credit Facility 4 Billion
Line of Credit Facility [Line Items]
Facility Limit	5,000,000,000	[3]
Outstanding Commercial Paper	3,437,000,000	[3]
Outstanding Letters of Credit	0	[3]
Facility Capacity Available	1,563,000,000	[3]
Credit Facility 4 Billion | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	5,000,000,000	[1]
Outstanding Commercial Paper	1,423,000,000	[1]
Outstanding Letters of Credit	0	[1]
Credit Facility 4 Billion | Dominion Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	1,000,000,000	[2]
Outstanding Commercial Paper	238,000,000	[2]
Outstanding Letters of Credit	0	[2]
Credit Facility 500 Million
Line of Credit Facility [Line Items]
Facility Limit	500,000,000	[3]
Outstanding Commercial Paper	0	[3]
Outstanding Letters of Credit	52,000,000	[3]
Facility Capacity Available	448,000,000	[3]
Credit Facility 500 Million | Virginia Electric and Power Company
Line of Credit Facility [Line Items]
Facility Limit	500,000,000	[1]
Outstanding Commercial Paper	0	[1]
Outstanding Letters of Credit	0	[1]
Credit Facility 500 Million | Dominion Gas Holdings, LLC
Line of Credit Facility [Line Items]
Facility Limit	500,000,000	[2]
Outstanding Commercial Paper	0	[2]
Outstanding Letters of Credit	$ 0	[2]

[1] The full amount of the facilities is available to Virginia Power, less any amounts outstanding to co-borrowers Dominion and Dominion Gas. Sub-limits for Virginia Power are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Virginia Power was $2.0 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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.

[2] A maximum of a combined $1.5 billion of the facilities is available to Dominion Gas, assuming adequate capacity is available after giving effect to uses by co-borrowers Dominion and Virginia Power. Sub-limits for Dominion Gas are set within the facility limit but can be changed at the option of the Companies multiple times per year. At June 30, 2016, the aggregate sub-limit for Dominion Gas was $1.0 billion. If Dominion 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. In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities 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.

[3] In May 2016, the maturity dates for these facilities were extended from April 2019 to April 2020. These credit facilities can be used 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.

XML

Commitments and Contingencies (Narrative) (Details)	1 Months Ended												6 Months Ended	12 Months Ended
	Jul. 31, 2016 party	Jun. 30, 2016 USD ($) facility party site	Apr. 30, 2016 USD ($)	Oct. 31, 2015	Jun. 30, 2015 party	Apr. 30, 2015 facility	Dec. 31, 2014 USD ($)	Oct. 31, 2014 facility	Jun. 30, 2014 unit	Jul. 31, 2013 unit	Sep. 30, 2011 party	Jul. 31, 2011 state group MW	Jun. 30, 2016 USD ($) facility party site	Dec. 31, 2015 USD ($) party
Investments in and Advances to Affiliates [Line Items]
Extension period for MATS compliance			1 year						1 year
Number of coal fired generating units | unit									2
Requested compliance extension under EPA Administrative Order				1 year
Maximum period for consideration of CO2 emissions from biomass projects												3 years
Number of parties issued UAO | party											22
Daily civil penalties for non compliance													$ 37,500
Coal Tar and Other Potentially Harmful Materials
Investments in and Advances to Affiliates [Line Items]
Number of former manufactured gas plant sites | site		17											17
Former Gas Plant Site with Post Closure Groundwater Monitoring Program | Coal Tar and Other Potentially Harmful Materials
Investments in and Advances to Affiliates [Line Items]
Number of former sites | site													1
Dominion Gas Holdings, LLC | Coal Tar and Other Potentially Harmful Materials
Investments in and Advances to Affiliates [Line Items]
Number of former manufactured gas plant sites | site		12											12
Virginia Electric and Power Company
Investments in and Advances to Affiliates [Line Items]
Number of coal fired generating units | unit										3
Virginia Electric and Power Company | Coal Tar and Other Potentially Harmful Materials
Investments in and Advances to Affiliates [Line Items]
Number of former manufactured gas plant sites | site		3											3
Preliminary costs for options under evaluation for site, minimum		$ 1,000,000											$ 1,000,000
Preliminary costs for options under evaluation for site, maximum		$ 22,000,000											$ 22,000,000
Virginia Electric and Power Company | Possum Point Power Station | Other operations and maintenance
Investments in and Advances to Affiliates [Line Items]
Charge as a result of settlement offer							$ 121,000,000
Virginia Electric and Power Company | Facilities Subject to CCR Final Rule | Environmental Protection Agency Final Rule Regulating Management of CCRs | EPA
Investments in and Advances to Affiliates [Line Items]
Number of facilities with CCR | facility						8
Obligations incurred during the period														$ 386,000,000
Virginia Electric and Power Company | Facilities Subject to CCR Final Rule | Environmental Protection Agency Final Rule Regulating Management of CCRs | EPA | Other operations and maintenance
Investments in and Advances to Affiliates [Line Items]
Incremental charge upon recognition of ARO														99,000,000
Virginia Electric and Power Company | Facilities Subject to CCR Final Rule | Environmental Protection Agency Final Rule Regulating Management of CCRs | ARO's | EPA
Investments in and Advances to Affiliates [Line Items]
Increase in property plant and equipment associated with asset retirement costs														166,000,000
Virginia Electric and Power Company | Facilities Subject to CCR Final Rule | Noncurrent Liabilities | Environmental Protection Agency Final Rule Regulating Management of CCRs | EPA
Investments in and Advances to Affiliates [Line Items]
Reduction in other current liabilities														$ 121,000,000
Virginia Electric and Power Company | Pending Litigation | Facilities Subject to CCR Final Rule | Environmental Protection Agency Final Rule Regulating Management of CCRs | EPA | Administrative Appeals in Circuit Court for the City of Richmond
Investments in and Advances to Affiliates [Line Items]
Number of parties | party														2
Virginia Electric and Power Company | Settled Litigation | Facilities Subject to CCR Final Rule | Environmental Protection Agency Final Rule Regulating Management of CCRs | EPA | Administrative Appeals in Circuit Court for the City of Richmond
Investments in and Advances to Affiliates [Line Items]
Number of parties | party		1
CAIR
Investments in and Advances to Affiliates [Line Items]
Number of states under EPA replacement rule | state												28
Emissions of fossil fuel fired electric generating units (MW) | MW												25
Number of groups of affected states | group												2
CWA
Investments in and Advances to Affiliates [Line Items]
Number of facilities that may be subject to final regulations | facility								14
CWA | Final Rule to Revise Effluent Limitations Guidelines for Steam Electric Power Generating Category | EPA
Investments in and Advances to Affiliates [Line Items]
Number of facilities that maybe subject to additional wastewater treatment requirements | facility		8											8
CWA | Virginia Electric and Power Company
Investments in and Advances to Affiliates [Line Items]
Number of facilities that may be subject to final regulations | facility								11
Unfavorable Regulatory Action | Dominion Gas Holdings, LLC | Regulations to Reduce Nitrogen Oxide and Volatile Organic Compounds Emissions | Pennsylvania Department of Environmental Protection
Investments in and Advances to Affiliates [Line Items]
Estimated compliance costs			$ 25,000,000
Breach of Contract Lawsuit | DTI | Pending Litigation
Investments in and Advances to Affiliates [Line Items]
Accrued liability for legal matter		$ 6,000,000											$ 6,000,000
Liquefaction Project | Cove Point | Pending Litigation
Investments in and Advances to Affiliates [Line Items]
Number of parties | party													2
Liquefaction Project | Cove Point | Judicial Ruling
Investments in and Advances to Affiliates [Line Items]
Number of parties | party					1
Liquefaction Project | Cove Point | Judicial Ruling | Subsequent Event
Investments in and Advances to Affiliates [Line Items]
Number of parties | party	1

XML

Commitments and Contingencies (Subsidiary Guarantees) (Details)	6 Months Ended
	Jun. 30, 2016 USD ($) guarantee subsidiary
Commitments and Contingencies [Line Items]
Stated Limit	$ 6,124,000,000
Value	$ 1,244,000,000	[1]
Number of DEI subsidiaries | subsidiary	2
Purchased surety bonds	$ 120,000,000
Authorized issuance of standby letters of credit	52,000,000
Minimum
Commitments and Contingencies [Line Items]
Annual future contributions	4,000,000
Maximum
Commitments and Contingencies [Line Items]
Annual future contributions	19,000,000
Third Party and Equity Method Investee
Commitments and Contingencies [Line Items]
Amount of civil penalty	73,000,000
Stated Limit	43,000,000
Cove Point
Commitments and Contingencies [Line Items]
Stated Limit	$ 150,000,000
Number of guarantees with no stated limit | guarantee	2
Number of guarantees | guarantee	1
Aggregate limit	$ 1,750,000,000
Annual draw limit	175,000,000
Subsidiary Debt
Commitments and Contingencies [Line Items]
Stated Limit	27,000,000	[2]
Value	27,000,000	[1],[2]
Commodity Transactions
Commitments and Contingencies [Line Items]
Stated Limit	2,074,000,000	[3]
Value	864,000,000	[1],[3]
Nuclear Obligations
Commitments and Contingencies [Line Items]
Stated Limit	189,000,000	[4]
Value	81,000,000	[1],[4]
Nuclear Obligations | Millstone
Commitments and Contingencies [Line Items]
Stated Limit	150,000,000
Nuclear Obligations | Kewaunee
Commitments and Contingencies [Line Items]
Stated Limit	60,000,000
Cove Point
Commitments and Contingencies [Line Items]
Stated Limit	1,900,000,000	[5]
Value	0	[1],[5]
Solar
Commitments and Contingencies [Line Items]
Stated Limit	1,514,000,000	[6]
Value	244,000,000	[1],[6]
Other
Commitments and Contingencies [Line Items]
Stated Limit	420,000,000	[7]
Value	28,000,000	[1],[7]
Through 2019 | Third Party and Equity Method Investee
Commitments and Contingencies [Line Items]
Stated Limit	45,000,000
Virginia Electric and Power Company
Commitments and Contingencies [Line Items]
Purchased surety bonds	69,000,000
Dominion Gas Holdings, LLC
Commitments and Contingencies [Line Items]
Purchased surety bonds	$ 21,000,000

[1] Represents the estimated portion of the guarantee's stated limit that is utilized as of June 30, 2016 based upon prevailing economic conditions and fact patterns specific to each guarantee arrangement. For those guarantees related to obligations that are recorded as liabilities by Dominion's subsidiaries, the value includes the recorded amount.

[2] Guarantee of debt of a DEI subsidiary. In the event of default by the subsidiary, Dominion would be obligated to repay such amounts.

[3] Guarantees related to commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power, Dominion Gas and DEI. These guarantees were provided to counterparties in order to facilitate physical and financial transactions in gas, oil, electricity, pipeline capacity, transportation and related commodities and services. If any of these subsidiaries fail to perform or pay under the contracts and the counterparties seek performance or payment, Dominion would be obligated to satisfy such obligation. Dominion and its subsidiaries receive similar guarantees as collateral for credit extended to others. The value provided includes certain guarantees that do not have stated limits.

[4] Guarantees related to certain DEI subsidiaries' potential retrospective premiums that could be assessed if there is a nuclear incident under Dominion's nuclear insurance programs and guarantees for a DEI subsidiary's and Virginia Power's commitment to buy nuclear fuel. Excludes Dominion's agreement to provide up to $150 million and $60 million to two DEI subsidiaries to pay the operating expenses of Millstone nuclear power station (in the event of a prolonged outage) and Kewaunee nuclear power station, respectively, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee nuclear power station also provides for funds through the completion of decommissioning.

[5] Guarantees related to Cove Point, in support of terminal services, transportation and construction. Two of the guarantees have no stated limit, one guarantee has a $150 million limit, and one guarantee has a $1.75 billion aggregate limit with an annual draw limit of $175 million.

[6] Includes guarantees to facilitate the development of solar projects including guarantees that do not have stated limits. Also includes guarantees entered into by DEI on behalf of certain subsidiaries to facilitate the acquisition and development of solar projects.

[7] Guarantees related to other miscellaneous contractual obligations such as leases, environmental obligations and construction projects. Also includes guarantees related to certain DEI subsidiaries' obligations for equity capital contributions and energy generation associated with Fowler Ridge and NedPower. As of June 30, 2016, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $45 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million. The value provided includes certain guarantees that do not have stated limits.

XML

Credit Risk (Narrative) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($) counterparty	Dec. 31, 2015 USD ($)
Concentration Risk and Guarantor Obligations [Line Items]
Gross credit exposure	$ 111
Number of counterparties | counterparty	0
Additional collateral to be posted if the credit related contingent features were triggered	$ 4	$ 12
Aggregate fair value of all derivative instruments with credit contingent provisions that are in a liability position	13	$ 49
Counterparty, A
Concentration Risk and Guarantor Obligations [Line Items]
Amount of exposure for single counterparty	$ 31
Investment Grade | Investment grade counterparties
Concentration Risk and Guarantor Obligations [Line Items]
Concentration risk, percentage (percentage)	88.00%

XML

Related-Party Transactions (Details) - USD ($)		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Derivative Asset		$ 354,000,000		$ 354,000,000		$ 388,000,000
Derivative Liabilities		473,000,000		473,000,000		343,000,000
Capital expenditures				3,160,000,000	$ 2,370,000,000
Virginia Electric and Power Company
Related Party Transaction [Line Items]
Derivative Asset		163,000,000		163,000,000		127,000,000
Derivative Liabilities		274,000,000		274,000,000		86,000,000
Commodity purchases from affiliates		99,000,000	$ 94,000,000	244,000,000	346,000,000
Services provided by affiliates	[1]	102,000,000	107,000,000	242,000,000	217,000,000
Services provided to affiliates		7,000,000	5,000,000	12,000,000	10,000,000
Capital expenditures				1,226,000,000	1,292,000,000
Outstanding borrowings, net of repayments, under money pool for non-regulated subsidiaries		0		0		0
Virginia Electric and Power Company | Affiliate
Related Party Transaction [Line Items]
Derivative Asset		36,000,000		36,000,000		13,000,000
Derivative Liabilities		3,000,000		3,000,000		22,000,000
Virginia Electric and Power Company | Affiliate | Services provided by affiliates
Related Party Transaction [Line Items]
Capital expenditures		38,000,000	38,000,000	77,000,000	73,000,000
Virginia Electric and Power Company | Principal Owner
Related Party Transaction [Line Items]
Short term demand note		0		0		376,000,000
Virginia Electric and Power Company | Other deferred credits and other liabilities
Related Party Transaction [Line Items]
Amounts due to Dominion		356,000,000		356,000,000		316,000,000
Virginia Electric and Power Company | Other deferred charges and other assets
Related Party Transaction [Line Items]
Amounts due from Dominion		98,000,000		98,000,000		77,000,000
Dominion Gas Holdings, LLC
Related Party Transaction [Line Items]
Derivative Asset		3,000,000		3,000,000		11,000,000
Derivative Liabilities		12,000,000		12,000,000		14,000,000
Amounts due from Dominion	[2]	3,000,000		3,000,000		1,000,000
Commodity purchases from affiliates		2,000,000	2,000,000	5,000,000	4,000,000
Services provided by affiliates	[3]	33,000,000	25,000,000	60,000,000	45,000,000
Services provided to affiliates		18,000,000	17,000,000	35,000,000	35,000,000
Capital expenditures				393,000,000	292,000,000
Other receivables	[4]	8,000,000		8,000,000		7,000,000
Customer receivables from related parties		10,000,000		10,000,000		4,000,000
Affiliated notes receivable	[5]	16,000,000		16,000,000		14,000,000
Dominion Gas Holdings, LLC | Revolving Credit Facility | IRCA
Related Party Transaction [Line Items]
Borrowings under IRCA						95,000,000
Dominion Gas Holdings, LLC | Services provided by affiliates
Related Party Transaction [Line Items]
Commodity purchases from affiliates	[6]	33,000,000	34,000,000	72,000,000	68,000,000
Dominion Gas Holdings, LLC | Affiliate | Services provided by affiliates
Related Party Transaction [Line Items]
Capital expenditures		14,000,000	$ 15,000,000	24,000,000	$ 24,000,000
Dominion Gas Holdings, LLC | Noncurrent Pension and Other Postretirement Benefit Assets
Related Party Transaction [Line Items]
Amounts due from Dominion, noncurrent		$ 674,000,000		$ 674,000,000		$ 652,000,000

[1] Includes capitalized expenditures of $38 million for both the three months ended June 30, 2016 and 2015, respectively, and $77 million and $73 million for the six months ended June 30, 2016 and 2015, respectively.

[2] Amounts are presented in other current assets in Dominion Gas' Consolidated Balance Sheets.

[3] Amounts primarily attributable to Atlantic Coast Pipeline.

[4] Represents amounts due from Atlantic Coast Pipeline, a related-party VIE.

[5] Amounts are presented in other deferred charges and other assets in Dominion Gas' Consolidated Balance Sheets.

[6] Includes capitalized expenditures of $14 million and $15 million for the three months ended June 30, 2016 and 2015, respectively, and $24 million for both the six months ended June 30, 2016 and 2015

XML

Employee Benefit Plans (Net Periodic Benefit Cost) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 28	$ 31	$ 57	$ 63
Interest cost	78	72	155	144
Expected return on plan assets	(139)	(133)	(278)	(266)
Amortization of prior service cost (credit)	1	1	1	1
Amortization of net actuarial loss	27	40	55	80
Net periodic benefit cost (credit)	(5)	11	(10)	22
Pension Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	4	7	7
Interest cost	7	7	15	14
Expected return on plan assets	(34)	(32)	(67)	(63)
Amortization of net actuarial loss	4	5	7	10
Net periodic benefit cost (credit)	(19)	(16)	(38)	(32)
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	8	10	16	20
Interest cost	17	16	34	33
Expected return on plan assets	(30)	(30)	(59)	(59)
Amortization of prior service cost (credit)	(7)	(6)	(14)	(13)
Amortization of net actuarial loss	2	2	3	3
Net periodic benefit cost (credit)	(10)	(8)	(20)	(16)
Other Postretirement Benefits | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	1	3	3
Interest cost	4	4	7	7
Expected return on plan assets	(7)	(6)	(12)	(12)
Amortization of net actuarial loss	1	0	1	1
Net periodic benefit cost (credit)	$ 0	$ (1)	$ (1)	$ (1)

XML

Employee Benefit Plans (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Contributions to defined benefit pension plans and OPEB plans	$ 0
Expected contribution to voluntary employees' beneficiary association	12,000,000
Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Contributions to defined benefit pension plans and OPEB plans	0
Expected contribution to voluntary employees' beneficiary association	12,000,000
Special Termination Benefits | Organizational Design Initiative
Defined Benefit Plan Disclosure [Line Items]
Organizational design initiative	65,000,000
Organizational design initiative, after tax	40,000,000
Special Termination Benefits | Organizational Design Initiative | Virginia Electric and Power Company
Defined Benefit Plan Disclosure [Line Items]
Organizational design initiative	33,000,000
Organizational design initiative, after tax	20,000,000
Special Termination Benefits | Organizational Design Initiative | Dominion Gas Holdings, LLC
Defined Benefit Plan Disclosure [Line Items]
Organizational design initiative	8,000,000
Organizational design initiative, after tax	$ 5,000,000

XML

Operating Segments (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
After tax net expense	$ 1,817,000,000	$ 1,974,000,000	$ 3,856,000,000	$ 4,381,000,000
Operating Segments
Segment Reporting Information [Line Items]
After tax net expenses			26,000,000	62,000,000
Operating Segments | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative			59,000,000
Organizational design initiative, after tax			36,000,000
Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
After tax net expenses			37,000,000	64,000,000
Operating Segments | DVP | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative, after tax			5,000,000
Operating Segments | Dominion Energy | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative, after tax			12,000,000
Operating Segments | Dominion Generation
Segment Reporting Information [Line Items]
Net gain on investments				45,000,000
Net gain on investments, after tax				28,000,000
Operating Segments | Dominion Generation | PJM
Segment Reporting Information [Line Items]
Billing adjustment				17,000,000
Billing adjustment, net of tax				10,000,000
Operating Segments | Dominion Generation | Facilities Subject to CCR Final Rule
Segment Reporting Information [Line Items]
Charge related to incremental future ash pond and landfill closure costs				45,000,000
Charge related to incremental future ash pond and landfill closure costs, after tax				28,000,000
Operating Segments | Dominion Generation | Virginia Regulation | Deferred Fuel Costs
Segment Reporting Information [Line Items]
Write off of deferred fuel balances				85,000,000
Write off of deferred fuel balances, net of tax				52,000,000
Operating Segments | Dominion Generation | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative, after tax			19,000,000
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
After tax net expense	1,223,000,000	1,332,000,000	2,599,000,000	2,944,000,000
Virginia Electric and Power Company | Operating Segments | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative			33,000,000
Organizational design initiative, after tax			20,000,000
Virginia Electric and Power Company | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
After tax net expenses				87,000,000
After tax net expense			19,000,000
Virginia Electric and Power Company | Operating Segments | DVP | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative, after tax			5,000,000
Virginia Electric and Power Company | Operating Segments | Dominion Generation | PJM
Segment Reporting Information [Line Items]
Billing adjustment				15,000,000
Billing adjustment, net of tax				9,000,000
Virginia Electric and Power Company | Operating Segments | Dominion Generation | Facilities Subject to CCR Final Rule
Segment Reporting Information [Line Items]
Charge related to incremental future ash pond and landfill closure costs				45,000,000
Charge related to incremental future ash pond and landfill closure costs, after tax				28,000,000
Virginia Electric and Power Company | Operating Segments | Dominion Generation | Virginia Regulation | Deferred Fuel Costs
Segment Reporting Information [Line Items]
Write off of deferred fuel balances				85,000,000
Write off of deferred fuel balances, net of tax				52,000,000
Virginia Electric and Power Company | Operating Segments | Dominion Generation | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative, after tax			15,000,000
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
After tax net expense	$ 182,000,000	$ 242,000,000	438,000,000	502,000,000
Dominion Gas Holdings, LLC | Operating Segments | Organizational Design Initiative
Segment Reporting Information [Line Items]
Organizational design initiative			8,000,000
Organizational design initiative, after tax			5,000,000
Dominion Gas Holdings, LLC | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
After tax net expenses				$ 0
After tax net expense			$ 2,000,000

XML

Operating Segments (Schedule of Segment Reporting Information, by Segment) (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting Information [Line Items]
Total revenue from external customers		$ 2,598	$ 2,747	$ 5,519	$ 6,156
Net income attributable to Dominion		452	413	976	949
DVP
Segment Reporting Information [Line Items]
Total revenue from external customers		518	505	1,079	1,074
Dominion Generation
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	1,566	1,658	3,262	3,650
Dominion Energy
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	515	578	1,178	1,424
Corporate and Other
Segment Reporting Information [Line Items]
Total revenue from external customers		136	148	331	277
Operating Segments | DVP
Segment Reporting Information [Line Items]
Total revenue from external customers		512	500	1,068	1,064
Net income attributable to Dominion		104	117	224	257
Operating Segments | Dominion Generation
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	1,564	1,652	3,257	3,641
Net income attributable to Dominion	[1]	171	250	416	512
Operating Segments | Dominion Energy
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	391	463	876	999
Net income attributable to Dominion	[1]	162	129	348	356
Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Total revenue from external customers		3	4	6	(9)
Net income attributable to Dominion		15	(83)	(12)	(176)
Intersegment revenue
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	(265)	(270)	(643)	(730)
Intersegment revenue | DVP
Segment Reporting Information [Line Items]
Total revenue from external customers		6	5	11	10
Intersegment revenue | Dominion Generation
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	2	6	5	9
Intersegment revenue | Dominion Energy
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	124	115	302	425
Intersegment revenue | Corporate and Other
Segment Reporting Information [Line Items]
Total revenue from external customers		133	144	325	286
Adjustments/Eliminations
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	128	128	312	461
Net income attributable to Dominion	[1]	0	0	0	0
Eliminations
Segment Reporting Information [Line Items]
Total revenue from external customers	[1]	(137)	(142)	(331)	(269)
Virginia Electric and Power Company
Segment Reporting Information [Line Items]
Total revenue from external customers	[2]	1,776	1,813	3,666	3,950
Net income attributable to Dominion		280	246	543	515
Virginia Electric and Power Company | Operating Segments | DVP
Segment Reporting Information [Line Items]
Total revenue from external customers		512	502	1,069	1,069
Net income attributable to Dominion		104	117	222	257
Virginia Electric and Power Company | Operating Segments | Dominion Generation
Segment Reporting Information [Line Items]
Total revenue from external customers		1,264	1,311	2,597	2,896
Net income attributable to Dominion		174	155	340	345
Virginia Electric and Power Company | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Total revenue from external customers		0	0	0	(15)
Net income attributable to Dominion		2	(26)	(19)	(87)
Dominion Gas Holdings, LLC
Segment Reporting Information [Line Items]
Total revenue from external customers	[3]	368	395	799	926
Net income attributable to Dominion		105	85	203	246
Dominion Gas Holdings, LLC | Operating Segments | Dominion Energy
Segment Reporting Information [Line Items]
Total revenue from external customers		368	395	799	926
Net income attributable to Dominion		108	87	211	251
Dominion Gas Holdings, LLC | Operating Segments | Corporate and Other
Segment Reporting Information [Line Items]
Total revenue from external customers		0	0	0	0
Net income attributable to Dominion		$ (3)	$ (2)	$ (8)	$ (5)

[1] 2015 amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Energy segment.

[2] See Note 17 for amounts attributable to affiliates.

[3] See Note 17 for amounts attributable to related parties.