Dominion Energy (D) 10-K 28 Feb 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jan. 31, 2014	Jun. 30, 2013
Document Information [Line Items]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
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	'	581,483,227	'
Entity Well Known Seasoned Issuer	'Yes	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Public Float	'	'	$32,100,000,000
Virginia Electric and Power Company	'	'	'
Document Information [Line Items]	'	'	'
Document Type	'10-K	'	'
Amendment Flag	'false	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
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	'
Entity Well Known Seasoned Issuer	'Yes	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Public Float	'	'	$0

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Operating Revenue	$13,120		$12,835	[1]	$13,765	[1]
Operating Expenses	'		'		'
Electric fuel and other energy-related purchases	3,885		3,645	[1]	3,942	[1]
Purchased electric capacity	358		387	[1]	454	[1]
Purchased gas	1,331		1,177	[1]	1,764	[1]
Other operations and maintenance	2,459		3,091	[1]	3,178	[1]
Depreciation, depletion and amortization	1,208		1,127	[1]	1,018	[1]
Other taxes	563		550	[1]	529	[1]
Total operating expenses	9,804		9,977	[1]	10,885	[1]
Income from operations	3,316		2,858	[1]	2,880	[1]
Other income	265		223	[1]	178	[1]
Interest and related charges	877		816	[1]	796	[1]
Income from continuing operations including noncontrolling interests before income taxes	2,704		2,265	[1]	2,262	[1]
Income tax expense	892	[2]	811	[1],[2]	778	[1],[2]
Income from continuing operations including noncontrolling interests	1,812		1,454	[1]	1,484	[1]
Income (loss) from discontinued operations	-92		-1,125	[1],[3]	-58	[1],[3]
Net income including noncontrolling interests	1,720		329	[1]	1,426	[1]
Noncontrolling interests	23		27	[1]	18	[1]
Net income attributable to Dominion	1,697		302	[1]	1,408	[1]
Amounts attributable to Dominion:	'		'		'
Income from continuing operations, net of tax	1,789	[4]	1,427	[1],[4]	1,466	[1]
Loss from discontinued operations, net of tax	-92		-1,125	[1]	-58	[1]
Net income attributable to Dominion	1,697		302	[1]	1,408	[1]
Earnings Per Common Share-Basic:	'		'		'
Income from continuing operations (in dollars per share)	$3.09	[4]	$2.49	[1],[4]	$2.56	[1]
Loss from discontinued operations (in dollars per share)	($0.16)	[4]	($1.96)	[1],[4]	($0.10)	[1]
Net income attributable to Dominion (in dollars per share)	$2.93		$0.53	[1]	$2.46	[1]
Earnings Per Common Share-Diluted:	'		'		'
Income from continuing operations (in dollars per share)	$3.09	[4]	$2.49	[1],[4]	$2.55	[1]
Loss from discontinued operations (in dollars per share)	($0.16)	[4]	($1.96)	[1],[4]	($0.10)	[1]
Net income attributable to Dominion (in dollars per share)	$2.93		$0.53	[1]	$2.45	[1]
Dividends declared per common share	$2.25		$2.11	[1]	$1.97	[1]
Virginia Electric and Power Company	'		'		'
Operating Revenue	7,295		7,226		7,246
Operating Expenses	'		'		'
Electric fuel and other energy-related purchases	2,304		2,368		2,506
Purchased electric capacity	358		386		452
Affiliated suppliers	290		305		306
Other	1,161		1,161		1,437
Depreciation, depletion and amortization	853		782		718
Other taxes	249		232		222
Total operating expenses	5,215		5,234		5,641
Income from operations	2,080		1,992		1,605
Other income	86		96		88
Interest and related charges	369		385		331
Income from continuing operations including noncontrolling interests before income taxes	1,797		1,703		1,362
Income tax expense	659	[5]	653	[5]	540	[5]
Net income attributable to Dominion	1,138		1,050		822
Amounts attributable to Dominion:	'		'		'
Net income attributable to Dominion	1,138		1,050		822
Preferred dividends	17		16		17
Balance available for common stock	$1,121		$1,034		$805
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.
[2]	In 2012, Dominion’s current federal income tax expense for continuing and discontinued operations includes a $195 million benefit related to a carryback of its 2012 net operating loss. In 2011, Dominion’s deferred federal income tax expense includes the recognition of a $346 million benefit, including $51 million related to discontinued operations, for its 2011 net operating loss expected to be used to reduce taxable income in future years.
[3]	Includes income tax benefit of $43 million, $692 million, and $33 million in 2013, 2012 and 2011, respectively. For 2012, includes impairment charges of $1.6 billion related to Brayton Point and Kincaid. See Note 6 for additional information.
[4]	Amounts attributable to Dominion's common shareholders.
[5]	In 2011, Virginia Power’s deferred federal income tax expense includes a $54 million benefit related to a portion of its 2011 net operating loss that is expected to be used in future years. Also, Virginia Power’s current federal income tax expense reflects the amounts of its 2011 net operating losses realized through its participation in a tax sharing agreement with Dominion and its subsidiaries.

Consolidated_Statements_of_Inc1

Consolidated Statements of Income (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2012	Dec. 31, 2011
EPS impact of recast Brayton Point and Kincaid discontinued operations	$1.92	$0.06
Discontinued operation tax expense	$692,000,000	$33,000,000

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2011
Net income including noncontrolling interests	$1,720	$329	[1]	$1,426	[1]
Net income attributable to Dominion	1,697	302	[1]	1,408	[1]
Other comprehensive income (loss), net of taxes:	'	'		'
Net deferred gains (losses) on derivatives-hedging activities, net of tax	-243	-8		-67
Changes in unrealized net gains (losses) on investment securities, net of tax	203	108		11
Changes in net unrecognized pension and other postretirement benefit costs, net of tax	516	-330		-231
Amounts reclassified to net income:	'	'		'
Net derivative (gains) losses-hedging activities, net of tax	77	-60		-38
Net realized gains on investment securities, net of tax	-55	-25		6
Net pension and other postretirement benefit costs, net of tax	55	48		39
Total other comprehensive income income (loss)	553	-267		-280
Comprehensive income including noncontrolling interests	2,273	62		1,146
Comprehensive income attributable to noncontrolling interests	23	27		18
Comprehensive income	2,250	35		1,128
Virginia Electric and Power Company	'	'		'
Net income attributable to Dominion	1,138	1,050		822
Other comprehensive income (loss), net of taxes:	'	'		'
Net deferred gains (losses) on derivatives-hedging activities, net of tax	6	-5		-6
Changes in unrealized net gains (losses) on investment securities, net of tax	20	13		2
Amounts reclassified to net income:	'	'		'
Net derivative (gains) losses-hedging activities, net of tax	0	2		-1
Net realized gains on investment securities, net of tax	-3	-4		0
Total other comprehensive income income (loss)	23	6		-5
Comprehensive income	$1,161	$1,056		$817
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net deferred gains (losses) on derivatives-hedging activities, tax	$161	$5	$48
Changes in unrealized net gains (losses) on investment securities, tax	-136	-68	-7
Changes in net unrecognized pension and other postretirement benefit costs, tax	-341	209	147
Net derivative (gains) losses-hedging activities, tax	-53	34	28
Net realized (gains) losses on investment securities, tax	35	16	-4
Net pension and other postretirement benefit costs, tax	-39	-32	-25
Virginia Electric and Power Company	'	'	'
Net deferred gains (losses) on derivatives-hedging activities, tax	-3	3	3
Changes in unrealized net gains (losses) on investment securities, tax	-13	-7	-1
Net derivative (gains) losses-hedging activities, tax	0	-2	0
Net realized (gains) losses on investment securities, tax	$2	$2	$0

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'		'
Cash and cash equivalents	$316		$248
Customer receivables	1,695		1,621
Other receivables	141		96
Inventories:	'		'
Materials and supplies	689		684
Fossil fuel	393		467
Gas stored	94		108
Derivative assets	687		518
Margin Deposit Assets	620		212
Prepayments	192		326
Regulatory assets	217	[1]	203	[1]
Deferred income taxes	778		573
Other	335		287
Total current assets	5,940		5,140
Investments	'		'
Nuclear decommissioning trust funds	3,903		3,330
Investment in equity method affiliates	916		558
Other	283		303
Total investments	5,102		4,191
Property, Plant and Equipment	'		'
Property, plant and equipment	46,969		43,364
Property, plant and equipment, VIE	0		957
Accumulated depreciation, depletion and amortization	-14,341		-13,548
Total property, plant and equipment, net	32,628		30,773
Deferred Charges and Other Assets	'		'
Goodwill	3,086	[2]	3,130	[2]
Pension and other postretirement benefit assets	942		702
Intangible assets, net	560		536
Regulatory assets	1,228		1,717
Other	610		649
Total deferred charges and other assets	6,426		6,734
Total assets	50,096		46,838
Current Liabilities	'		'
Securities due within one year	1,519		1,363
Securities due within one year, VIE	0		860
Short-term debt	1,927		2,412
Accounts payable	1,168		1,137
Accrued interest, payroll and taxes	609		636
Derivative liabilities	828		510
Regulatory liabilities	128	[3]	136	[3]
Other	943		845
Total current liabilities	6,994		7,763
Long-Term Debt	'		'
Long-term debt	16,877		15,478
Junior subordinated notes	1,373		1,373
Remarketable Subordinated Notes, Noncurrent	1,080		0
Total long-term debt	19,330		16,851
Deferred Credits and Other Liabilities	'		'
Deferred income taxes and investment tax credits	7,114		5,800
Asset retirement obligations	1,484		1,641
Pension and other postretirement benefit liabilities	481		1,831
Regulatory liabilities	2,001		1,514
Other	793		556
Total deferred credits and other liabilities	11,873		11,342
Total liabilities	38,197		35,956
Subsidiary Preferred Stock Not Subject To Mandatory Redemption	257		257
Equity	'		'
Common stock-no par	5,783	[4]	5,493	[4]
Other paid-in capital	0		162
Retained earnings	6,183		5,790
Accumulated other comprehensive loss	-324		-877
Total common shareholders' equity	11,642		10,568
Noncontrolling interest	0		57
Total equity	11,642		10,625
Total liabilities and equity	50,096		46,838
Virginia Electric and Power Company	'		'
Current Assets	'		'
Cash and cash equivalents	16		28
Customer receivables	946		849
Other receivables	78		51
Inventories:	'		'
Materials and supplies	418		385
Fossil fuel	390		404
Prepayments	32		23
Regulatory assets	128		119
Deferred income taxes	87		92
Other	68		30
Total current assets	2,163		1,981
Investments	'		'
Nuclear decommissioning trust funds	1,765		1,515
Other	12		14
Total investments	1,777		1,529
Property, Plant and Equipment	'		'
Property, plant and equipment	32,848		30,631
Accumulated depreciation, depletion and amortization	-10,580		-10,014
Total property, plant and equipment, net	22,268		20,617
Deferred Charges and Other Assets	'		'
Intangible assets, net	193		181
Regulatory assets	417		396
Other	143		107
Total deferred charges and other assets	753		684
Total assets	26,961		24,811
Current Liabilities	'		'
Securities due within one year	58		418
Short-term debt	842		992
Accounts payable	479		430
Payables to affiliates	69		67
Affiliated current borrowings	97		435
Accrued interest, payroll and taxes	218		204
Derivative liabilities	12		33
Customer deposits	95		100
Regulatory liabilities	41		32
Other	306		296
Total current liabilities	2,217		3,007
Long-Term Debt	'		'
Total long-term debt	7,974		6,251
Deferred Credits and Other Liabilities	'		'
Deferred income taxes and investment tax credits	4,137		3,879
Asset retirement obligations	689		705
Regulatory liabilities	1,597		1,285
Other	292		194
Total deferred credits and other liabilities	6,715		6,063
Total liabilities	16,906		15,321
Subsidiary Preferred Stock Not Subject To Mandatory Redemption	257		257
Equity	'		'
Common stock-no par	5,738	[5]	5,738	[5]
Other paid-in capital	1,113		1,113
Retained earnings	2,899		2,357
Accumulated other comprehensive loss	48		25
Total common shareholders' equity	9,798		9,233
Total equity	9,798		9,233
Total liabilities and equity	$26,961		$24,811
[1]	Current regulatory assets are presented in other current assets in Dominion's Consolidated Balance Sheets.
[2]	Goodwill amounts do not contain any accumulated impairment losses.
[3]	Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
[4]	1 billion shares authorized; 581 million shares and 576 million shares outstanding at December 31, 2013 and 2012, respectively.
[5]	shares authorized at December 31, 2013 and 2012; 274,723 shares outstanding at December 31, 2013 and 2012.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Allowance - Customer Receivables	$25	$28
Allowance - Other	4	4
Common Stock, shares authorized	1,000,000,000	1,000,000,000
Common stock, shares outstanding	581,000,000	576,000,000
Virginia Electric and Power Company	'	'
Allowance - Customer Receivables	11	10
Allowance - Other	$2	$3
Common Stock, shares authorized	500,000	500,000
Common stock, shares outstanding	274,723	274,723

Consolidated_Statements_Equity

Consolidated Statements Equity (USD $)

Total

Common Stock

Other Paid-In Capital

Retained Earnings

Accumulated Other Comprehensive Income (Loss)

Total Common Shareholders' Equity

Noncontrolling Interests

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

In Millions, unless otherwise specified

Common Stock

Other Paid-In Capital

Retained Earnings

Accumulated Other Comprehensive Income (Loss)

Beginning Balance, value at Dec. 31, 2010

$11,997

$5,715

$194

$6,418

($330)

$11,997

$0

$8,507

$5,738

$1,111

$1,634

$24

Beginning Balance (in shares) at Dec. 31, 2010

'

581

'

'

'

'

'

'

275

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

1,426

[1]

'

'

1,425

'

1,425

1

'

'

'

'

'

Net income attributable to Dominion

1,408

[1]

'

'

'

'

'

'

822

'

'

822

'

Consolidation of non-controlling interests

[2]

61

'

'

'

'

'

61

'

'

'

'

'

Consolidation of noncontrolling interests, (in shares)

'

1

'

'

'

'

'

'

'

'

'

'

Consolidation of noncontrolling interests, value

49

49

'

'

'

49

'

'

'

'

'

'

Stock awards and stock options exercised (net of change in unearned compensation) (in shares)

'

-13

'

'

'

'

'

'

'

'

'

'

Stock awards and stock options exercised (net of change in unearned compensation), value

-601

-601

'

'

'

-601

'

'

'

'

'

'

Stock repurchases (in shares)

[3]

'

1

'

'

'

'

'

'

'

'

'

'

Stock repurchases, value

[3]

0

17

-17

'

'

0

'

'

'

'

'

'

Tax benefit from stock awards and stock options exercised

2

'

2

'

'

2

'

'

'

'

'

'

Dividends

-1,151

'

'

-1,146

[4]

'

-1,146

-5

-574

'

'

-574

'

Tax benefit from stock awards and stock options exercised

13

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income, net of tax

-280

'

'

'

-280

-280

'

-5

'

'

'

-5

Beginning Balance, value at Dec. 31, 2011

11,503

5,180

179

6,697

-610

11,446

57

8,750

5,738

'

1,882

19

Ending Balance (shares) at Dec. 31, 2011

'

570

'

'

'

'

'

'

275

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

501

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to Dominion

494

'

'

'

'

'

'

243

'

'

'

'

Beginning Balance, value at Mar. 31, 2012

'

'

'

'

'

'

'

'

'

'

'

'

Beginning Balance, value at Dec. 31, 2011

11,503

5,180

179

6,697

-610

11,446

57

8,750

5,738

1,111

1,882

19

Beginning Balance (in shares) at Dec. 31, 2011

'

570

'

'

'

'

'

'

275

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

329

[1]

'

'

318

'

318

11

'

'

'

'

'

Net income attributable to Dominion

302

[1]

'

'

'

'

'

'

1,050

'

'

1,050

'

Consolidation of noncontrolling interests, (in shares)

'

4

'

'

'

'

'

'

'

'

'

'

Consolidation of noncontrolling interests, value

246

246

'

'

'

246

'

'

'

'

'

'

Stock awards and stock options exercised (net of change in unearned compensation) (in shares)

'

-1

'

'

'

'

'

'

'

'

'

'

Stock awards and stock options exercised (net of change in unearned compensation), value

26

26

'

'

'

26

'

'

'

'

'

'

Other stock issuances (in shares)

[3]

'

-1

'

'

'

'

'

'

'

'

'

'

Other stock issuances, value

[3]

14

41

-27

'

'

14

'

'

'

'

'

'

Tax benefit from stock awards and stock options exercised

10

'

10

'

'

10

'

'

'

'

'

'

Dividends

-1,236

'

'

-1,225

[4]

'

-1,225

-11

-575

'

'

-575

'

Tax benefit from stock awards and stock options exercised

8

'

'

'

'

'

'

2

'

2

'

'

Other comprehensive income, net of tax

-267

'

'

'

-267

-267

'

6

'

'

'

6

Beginning Balance, value at Dec. 31, 2012

10,625

5,493

162

5,790

-877

10,568

57

9,233

5,738

1,113

2,357

25

Ending Balance (shares) at Dec. 31, 2012

'

576

'

'

'

'

'

'

275

'

'

'

Beginning Balance, value at Sep. 30, 2012

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

-652

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to Dominion

-659

'

'

'

'

'

'

220

'

'

'

'

Beginning Balance, value at Dec. 31, 2012

10,625

'

'

'

'

'

'

9,233

5,738

'

'

'

Ending Balance (shares) at Dec. 31, 2012

'

'

'

'

'

'

'

'

275

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

502

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to Dominion

495

'

'

'

'

'

'

287

'

'

'

'

Beginning Balance, value at Mar. 31, 2013

'

'

'

'

'

'

'

'

'

'

'

'

Beginning Balance, value at Dec. 31, 2012

10,625

5,493

162

5,790

-877

10,568

57

9,233

5,738

'

2,357

25

Beginning Balance (in shares) at Dec. 31, 2012

'

576

'

'

'

'

'

'

275

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

1,720

'

'

1,714

'

1,714

6

'

'

'

'

'

Net income attributable to Dominion

1,697

'

'

'

'

'

'

1,138

'

'

1,138

'

Consolidation of noncontrolling interests, (in shares)

'

4

'

'

'

'

'

'

'

'

'

'

Consolidation of noncontrolling interests, value

278

278

'

'

'

278

'

'

'

'

'

'

Stock awards and stock options exercised (net of change in unearned compensation), value

12

12

'

'

'

12

'

'

'

'

'

'

Other stock issuances (in shares)

[5]

'

-1

'

'

'

'

'

'

'

'

'

'

Other stock issuances, value

[5]

7

15

-8

'

'

7

'

'

'

'

'

'

Present value of stock purchase contract payments related to RSNs(5)

[6]

-156

'

-154

-2

'

-156

'

'

'

'

'

'

Fairless lease buyout

[7]

-72

-15

'

'

'

-15

-57

'

'

'

'

'

Dividends

-1,325

'

'

-1,319

[4]

'

-1,319

-6

-596

'

'

-596

'

Tax benefit from stock awards and stock options exercised

11

'

'

'

'

'

'

'

'

'

'

'

Other comprehensive income, net of tax

553

'

'

'

553

553

'

23

'

'

'

23

Beginning Balance, value at Dec. 31, 2013

11,642

5,783

0

6,183

-324

11,642

0

9,798

5,738

1,113

2,899

48

Ending Balance (shares) at Dec. 31, 2013

'

581

'

'

'

'

'

'

275

'

'

'

Beginning Balance, value at Sep. 30, 2013

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

Net income including noncontrolling interests

[8]

435

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to Dominion

431

[8]

'

'

'

'

'

'

199

'

'

'

'

Beginning Balance, value at Dec. 31, 2013

$11,642

'

'

'

'

'

'

$9,798

$5,738

$1,113

'

'

Ending Balance (shares) at Dec. 31, 2013

'

'

'

'

'

'

'

'

275

'

'

'

[1]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

[2]

See Note 15 for consolidation of a VIE in October 2011.

[3]

Contains shares issued in excess of principal amounts related to converted securities. See Note 17 for further information on convertible securities.

[4]

Includes subsidiary preferred dividends related to noncontrolling interests of $17 million, $16 million and $17 million in 2013 and 2012 and 2011, respectively.

[5]

Primarily includes $28 million in shares issued in excess of principal amounts related to converted securities. See Note 17 for further information on convertible securities.

[6]

See Note 17 for further information.

[7]

See Note 15 for further information.

[8]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.

Consolidated_Statements_of_Equ

Consolidated Statements of Equity (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Preferred dividends related to noncontrolling interest	$17	$16	$17
Shares issued in excess of principal amounts related to converted securities	$28	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2011		Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
						Virginia Electric and Power Company	Virginia Electric and Power Company	Virginia Electric and Power Company
Operating Activities	'	'		'		'	'	'
Net income including noncontrolling interests	$1,720	$329	[1]	$1,426	[1]	'	'	'
Net income (loss) attributable to Dominion	1,697	302	[1]	1,408	[1]	1,138	1,050	822
Adjustments to reconcile net income including noncontrolling interests to net cash provided by operating activities:	'	'		'		'	'	'
Impairment of generation assets	48	2,089		283		0	0	228
Net reserves (payments) related to rate refunds	-5	-151		3		-5	-151	3
Depreciation, depletion and amortization (including nuclear fuel)	1,390	1,443		1,288		1,016	927	838
Deferred income taxes and investment tax credits	737	246		756		240	502	496
Gains on the sale of assets	-122	-81		0		'	'	'
Other adjustments	-129	-164		-207		-63	-70	-93
Changes in:	'	'		'		'	'	'
Accounts receivable	-98	292		365		-124	126	76
Affiliated accounts receivable and payable	'	'		'		3	-2	-7
Inventories	-29	33		-185		-19	8	-200
Deferred fuel and purchased gas costs, net	102	368		-3		93	378	12
Prepayments	123	-85		-19		-9	18	24
Accounts payable	50	-61		-413		15	19	-117
Accrued interest, payroll and taxes	-27	-12		-216		14	-22	12
Increase (Decrease) in Margin Deposits Outstanding	-414	45		-71		'	'	'
Other operating assets and liabilities	87	-154		-24		30	-77	-70
Net cash provided by operating activities	3,433	4,137		2,983		2,329	2,706	2,024
Investing Activities	'	'		'		'	'	'
Plant construction and other property additions (including nuclear fuel)	-4,104	-4,145		-3,652		-2,394	-2,082	-1,885
Purchases of nuclear fuel	'	'		'		-139	-206	-205
Purchases of securities	'	'		'		-603	-638	-1,057
Proceeds from sales of securities	'	'		'		572	626	1,030
Proceeds from sales of securities	1,476	1,356		1,757		'	'	'
Purchases of securities	-1,493	-1,392		-1,824		'	'	'
Proceeds from the sale of Brayton Point, Kincaid and equity method investment in Elwood	465	0		0		'	'	'
Proceeds from Blue Racer	33	58		55		'	'	'
Restricted cash equivalents	25	108		259		2	22	137
Other	13	118		139		-39	-4	33
Net cash used in investing activities	-3,458	-3,840		-3,321		-2,601	-2,282	-1,947
Financing Activities	'	'		'		'	'	'
Issuance (repayment) of short-term debt, net	-485	598		429		-151	98	294
Issuance of short-term notes	400	400		0		'	'	'
Repayment of short-term notes	-400	0		0		'	'	'
Issuance (repayment) of affiliated current borrowings, net	'	'		'		-338	248	85
Issuance and remarketing of long-term debt	4,135	1,500		2,320		1,835	450	235
Repayment and repurchase of long-term debt, including redemption premiums	-1,245	-1,675		-637		'	'	'
Repayment and repurchase of long-term debt	-258	0		0		-470	-641	-91
Acquisition of Juniper noncontrolling interest in Fairless	-923	0		0		'	'	'
Issuance of common stock	278	265		38		'	'	'
Repurchase of common stock	0	0		-601		'	'	'
Common dividend payments	-1,302	-1,209		-1,129		-579	-559	-557
Subsidiary preferred dividend payments	-17	-16		-17		-17	-16	-17
Other	-90	-14		-25		-20	-5	-2
Net cash provided by (used in) financing activities	93	-151		378		260	-425	-53
Increase in cash and cash equivalents	68	146		40		-12	-1	24
Cash and cash equivalents at beginning of year	248	102		62		28	29	5
Cash and cash equivalents at end of year	316	248		102		16	28	29
Supplemental Cash Flow Information	'	'		'		'	'	'
Interest and related charges, excluding capitalized amounts	852	913		920		328	376	376
Income taxes	56	-58		166		427	225	-27
Significant noncash investing and financing activities:	'	'		'		'	'	'
Accrued capital expenditures	375	388		328		276	242	199
Consolidation of VIE - assets at fair value	0	0		957		'	'	'
Consolidation of VIE - debt	$0	$0		$896		'	'	'
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

Nature_of_Operations

Nature of Operations	12 Months Ended
	Dec. 31, 2013
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, a regulated public utility that generates, transmits and distributes electricity for sale in Virginia and North Carolina. Virginia Power is a member of PJM, an RTO, and its electric transmission facilities are integrated into the PJM wholesale electricity markets. All of Virginia Power's common stock is owned by Dominion. Dominion's operations also include a regulated interstate natural gas transmission pipeline and underground storage system in the Northeast, mid-Atlantic and Midwest states, an LNG import, transport and storage facility in Maryland and regulated gas transportation and distribution operations in Ohio and West Virginia. Dominion's nonregulated operations include merchant generation, energy marketing and price risk management activities and retail energy marketing operations.
	In the second quarter of 2013, Dominion commenced a restructuring of its producer services business. The restructuring will result in the termination of natural gas trading and certain energy marketing activities. The restructuring is intended to reduce producer services' earnings volatility, and is not expected to have a material impact on Dominion's business.
	Dominion manages its daily operations through three primary operating segments: DVP, Dominion Generation and Dominion Energy. Dominion also reports a Corporate and Other segment, which includes its corporate, service company and other functions (including unallocated debt) and the net impact of operations that are discontinued, which is discussed in Note 3. 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 allocating resources among the segments.
	Virginia Power manages its daily operations through two primary operating segments: DVP and Dominion Generation. It also reports a Corporate and Other segment that 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 allocating resources among the segments. See Note 25 for further discussion of Dominion's and Virginia Power's operating segments.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	SIGNIFICANT ACCOUNTING POLICIES
	General
	Dominion and Virginia Power 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, expenses and cash flows for the periods presented. Actual results may differ from those estimates.
	Dominion's and Virginia Power's Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of their respective majority-owned subsidiaries and those VIEs where Dominion has been determined to be the primary beneficiary.
	Dominion and Virginia Power report certain contracts, instruments and investments at fair value. See Note 6 for further information on fair value measurements.
	Dominion maintains pension and other postretirement benefit plans. Virginia Power participates in certain of these plans. See Note 21 for further information on these plans.
	Certain amounts in the 2012 and 2011 Consolidated Financial Statements and footnotes have been reclassified to conform to the 2013 presentation for comparative purposes. The reclassifications did not affect the Companies' net income, total assets, liabilities, equity or cash flows.
	Amounts disclosed for Dominion are inclusive of Virginia Power, where applicable.
	Operating Revenue
	Operating revenue is recorded on the basis of services rendered, commodities delivered or contracts settled and includes amounts yet to be billed to customers. The Companies collect sales, consumption and consumer utility taxes; however, these amounts are excluded from revenue. Dominion's customer receivables at December 31, 2013 and 2012 included $555 million and $411 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to its utility customers. Virginia Power's customer receivables at December 31, 2013 and 2012 included $395 million and $348 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers.
	The primary types of sales and service activities reported as operating revenue for Dominion are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;
	•	Nonregulated electric sales consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity;
	•	Regulated gas sales consist primarily of state-regulated retail natural gas sales and related distribution services;
	•	Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity;
	•	Gas transportation and storage consists primarily of regulated sales of gathering, transmission, distribution and storage services and associated derivative activity. Also included are regulated gas distribution charges to retail distribution service customers opting for alternate suppliers; and
	•	Other revenue consists primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also includes miscellaneous service revenue from electric and gas distribution operations, and gas processing and handling revenue.
	The primary types of sales and service activities reported as operating revenue for Virginia Power are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales and federally-regulated wholesale electric sales and electric transmission services; and
	•	Other revenue consists primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities.
	Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs
	Where permitted by regulatory authorities, the differences between Virginia Power's actual electric fuel and purchased energy expenses and Dominion's purchased gas expenses and the related levels of recovery for these expenses in current rates are deferred and matched against recoveries in future periods. The deferral of costs in excess of current period fuel rate recovery is recognized as a regulatory asset, while rate recovery in excess of current period fuel expenses is recognized as a regulatory liability.
	Of the cost of fuel used in electric generation and energy purchases to serve utility customers, approximately 84% is currently subject to deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms.
	Income Taxes
	A consolidated federal income tax return is filed for Dominion and its subsidiaries, including Virginia Power. In addition, where applicable, combined income tax returns for Dominion and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed. Virginia Power participates in an intercompany tax sharing agreement with Dominion and its subsidiaries, and its current income taxes are based on its taxable income or loss, determined on a separate company basis.
	Accounting for income taxes involves an asset and liability approach. Deferred income tax assets and liabilities are provided, representing future effects on income taxes for temporary differences between the bases of assets and liabilities for financial reporting and tax purposes. Dominion and Virginia Power establish a valuation allowance when it is more-likely-than-not that all, or a portion, of a deferred tax asset will not be realized. Where the treatment of temporary differences is different for rate-regulated operations, a regulatory asset is recognized if it is probable that future revenues will be provided for the payment of deferred tax liabilities.
	Dominion and Virginia Power recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information.
	If it is not more-likely-than-not that a tax position, or some portion thereof, will be sustained, the related tax benefits are not recognized in the financial statements. Unrecognized tax benefits may result in an increase in income taxes payable, a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in income taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Except when such amounts are presented net with amounts receivable from or amounts prepaid to tax authorities, noncurrent income taxes payable related to unrecognized tax benefits are classified in other deferred credits and other liabilities on the consolidated balance sheets and current payables are included in accrued interest, payroll and taxes on the consolidated balance sheets.
	Dominion and Virginia Power recognize changes in estimated interest payable on net underpayments of income taxes in interest expense. Changes in interest receivable related to net overpayments of income taxes and estimated penalties that may result from the settlement of some uncertain tax positions are recognized in other income. In its Consolidated Statements of Income for 2013, Dominion recognized interest income of $3 million and interest expense of $10 million and no penalties. In 2012, Dominion recognized interest income of $8 million and interest expense of $3 million and a reduction in penalties of less than $1 million. In 2011, Dominion recognized interest income of $12 million and interest expense of $7 million and a reduction in penalties of less than $1 million. Dominion had accrued interest receivable of $5 million, interest payable of $15 million and penalties payable of less than $1 million at December 31, 2013 and interest receivable of $5 million, interest payable of $10 million and penalties payable of less than $1 million at December 31, 2012.
	Virginia Power's interest and penalties were immaterial in 2013 and 2012. In 2011, Virginia Power recognized interest income of $12 million, and penalties were immaterial.
	At December 31, 2013, Virginia Power's Consolidated Balance Sheet included $3 million of state income taxes receivable, $22 million of federal and state income taxes payable, $12 million of noncurrent state income taxes receivable and $28 million of noncurrent federal and state income taxes payable.
	At December 31, 2012, Virginia Power's Consolidated Balance Sheet included $10 million of federal income taxes payable and $36 million of noncurrent federal and state income taxes payable.
	Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold.
	Cash and Cash Equivalents
	Current banking arrangements generally do not require checks to be funded until they are presented for payment. At December 31, 2013 and 2012, Dominion's accounts payable included $38 million and $53 million, respectively, of checks outstanding but not yet presented for payment. At December 31, 2013 and 2012, Virginia Power's accounts payable included $21 million and $30 million, respectively, of checks outstanding but not yet presented for payment. For purposes of the Consolidated Statements of Cash Flows, cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less.
	Derivative Instruments
	Dominion and Virginia Power use derivative instruments such as futures, swaps, forwards, options and FTRs to manage the commodity, currency exchange and financial market risks of their business operations.
	All derivatives, other than those for which an exception applies, are reported in the Consolidated Balance Sheets at fair value. Derivative contracts representing unrealized gain positions and purchased options are reported as derivative assets. Derivative contracts representing unrealized losses and options sold are reported as derivative liabilities. One of the exceptions to fair value accounting, normal purchases and normal sales, may be elected when the contract satisfies certain criteria, including a requirement that physical delivery of the underlying commodity is probable. Expenses and revenues resulting from deliveries under normal purchase contracts and normal sales contracts, respectively, are included in earnings at the time of contract performance.
	Dominion and Virginia Power do not offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Dominion had margin assets of $620 million and $212 million associated with cash collateral at December 31, 2013 and 2012, respectively. Dominion had margin liabilities of $2 million and $4 million associated with cash collateral at December 31, 2013 and 2012, respectively. Virginia Power had margin assets of $11 million and $18 million associated with cash collateral at December 31, 2013 and 2012, respectively. Virginia Power's margin liabilities associated with cash collateral were not material at December 31, 2013 and 2012. See Note 7 for further information about offsetting derivatives.
	To manage price risk, Dominion and Virginia Power hold certain derivative instruments that are not held for trading purposes and are not designated as hedges for accounting purposes. However, to the extent the Companies do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices, interest rates and foreign exchange rates. As part of Dominion's strategy to market energy and manage related risks, it also manages a portfolio of commodity-based financial derivative instruments held for trading purposes. Dominion uses established policies and procedures to manage the risks associated with price fluctuations in these energy commodities and uses various derivative instruments to reduce risk by creating offsetting market positions.
	Statement of Income Presentation:
	•	Derivatives Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue on a net basis.
	•	Derivatives Not Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses or interest and related charges based on the nature of the underlying risk.
	In Virginia Power's generation operations, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities for jurisdictions subject to cost-based rate regulation. Realized gains or losses on the derivative instruments are generally recognized when the related transactions impact earnings.
	DERIVATIVE INSTRUMENTS DESIGNATED AS HEDGING INSTRUMENTS
	Dominion and Virginia Power designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. For all derivatives designated as hedges, Dominion and Virginia Power formally document the relationship between the hedging instrument and the hedged item, as well as the risk management objective and the strategy for using the hedging instrument. The Companies assess whether the hedging relationship between the derivative and the hedged item is highly effective at offsetting changes in cash flows or fair values both at the inception of the hedging relationship and on an ongoing basis. Any change in the fair value of the derivative that is not effective at offsetting changes in the cash flows or fair values of the hedged item is recognized currently in earnings. Also, the Companies may elect to exclude certain gains or losses on hedging instruments from the assessment of hedge effectiveness, such as gains or losses attributable to changes in the time value of options or changes in the difference between spot prices and forward prices, thus requiring that such changes be recorded currently in earnings. Hedge accounting is discontinued prospectively for derivatives that cease to be highly effective hedges. For derivative instruments that are accounted for as fair value hedges or cash flow hedges, the cash flows from the derivatives and from the related hedged items are classified in operating cash flows.
	Cash Flow Hedges-A majority of Dominion's and Virginia Power's hedge strategies represents cash flow hedges of the variable price risk associated with the purchase and sale of electricity, natural gas and other energy-related products. The Companies also use foreign currency contracts to hedge the variability in foreign exchange rates and interest rate swaps to hedge their exposure to variable interest rates on long-term debt. For transactions in which Dominion and Virginia Power are hedging the variability of cash flows, changes in the fair value of the derivatives are reported in AOCI, to the extent they are effective at offsetting changes in the hedged item. Any derivative gains or losses reported in AOCI are reclassified to earnings when the forecasted item is included in earnings, or earlier, if it becomes probable that the forecasted transaction will not occur. For cash flow hedge transactions, hedge accounting is discontinued if the occurrence of the forecasted transaction is no longer probable.
	Fair Value Hedges-Dominion also uses fair value hedges to mitigate the fixed price exposure inherent in certain firm commodity commitments and commodity inventory. In addition, Dominion and Virginia Power have designated interest rate swaps as fair value hedges on certain fixed rate long-term debt to manage interest rate exposure. For fair value hedge transactions, changes in the fair value of the derivative are generally offset currently in earnings by the recognition of changes in the hedged item's fair value. Derivative gains and losses from the hedged item are reclassified to earnings when the hedged item is included in earnings, or earlier, if the hedged item no longer qualifies for hedge accounting. Hedge accounting is discontinued if the hedged item no longer qualifies for hedge accounting.
	See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. See Note 7 for further information on derivatives.
	Property, Plant and Equipment
	Property, plant and equipment is recorded at lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs such as asset retirement costs, capitalized interest and, for certain operations subject to cost-of-service rate regulation, AFUDC and overhead costs. The cost of repairs and maintenance, including minor additions and replacements, is generally charged to expense as it is incurred.
	In 2013, 2012 and 2011, Dominion capitalized interest costs and AFUDC to property, plant and equipment of $66 million, $91 million and $85 million, respectively. In 2013, 2012 and 2011, Virginia Power capitalized AFUDC to property, plant and equipment of $33 million, $31 million and $31 million, respectively. Under Virginia law, certain Virginia jurisdictional projects qualify for current recovery of AFUDC through rate adjustment clauses. AFUDC on these projects is calculated and recorded as a regulatory asset and is not capitalized to property, plant and equipment. In 2013, 2012 and 2011, Virginia Power recorded $32 million, $37 million and $20 million of AFUDC related to these projects, respectively.
	For property subject to cost-of-service rate regulation, including Virginia Power electric distribution, electric transmission, and generation property and for certain Dominion natural gas property, the undepreciated cost of such property, less salvage value, is generally charged to accumulated depreciation at retirement. Cost of removal collections from utility customers not representing AROs are recorded as regulatory liabilities. For property subject to cost-of-service rate regulation that will be retired or abandoned significantly before the end of its useful life, the net carrying value is reclassified from plant-in-service when it becomes probable it will be retired or abandoned.
	For Dominion and Virginia Power property that is not subject to cost-of-service rate regulation, including nonutility property, cost of removal not associated with AROs is charged to expense as incurred. The Companies also record gains and losses upon retirement based upon the difference between the proceeds received, if any, and the property's net book value at the retirement date.
	Depreciation of property, plant and equipment is computed on the straight-line method based on projected service lives. Dominion's and Virginia Power's average composite depreciation rates on utility property, plant and equipment are as follows:
	Year Ended December 31,	2013	2012	2011
	(percent)
	Dominion
	Generation	2.71	2.62	2.68
	Transmission	2.36	2.17	2.26
	Distribution	3.13	3.17	3.19
	Storage	2.43	2.59	2.64
	Gas gathering and processing	2.39	2.49	2.52
General and other	3.82	4.55	4.66
Virginia Power
Generation	2.71	2.62	2.68
Transmission	2.28	1.98	2.03
Distribution	3.33	3.32	3.33
General and other	3.51	4.32	4.38
Dominion's nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives:
Asset	Estimated Useful Lives
Merchant generation-nuclear	44 years
Merchant generation-other	15-36 years
General and other	5-59 years
Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production basis. Dominion and Virginia Power report the amortization of nuclear fuel in electric fuel and other energy-related purchases expense in their Consolidated Statements of Income and in depreciation and amortization in their Consolidated Statements of Cash Flows.
Long-Lived and Intangible Assets
Dominion and Virginia Power perform an evaluation for impairment whenever events or changes in circumstances indicate that the carrying amount of long-lived assets or intangible assets with finite lives may not be recoverable. A long-lived or intangible asset is written down to fair value if the sum of its expected future undiscounted cash flows is less than its carrying amount. Intangible assets with finite lives are amortized over their estimated useful lives. See Note 6 for a discussion of impairments related to certain long-lived assets and intangible assets with finite lives.
Regulatory Assets and Liabilities
The accounting for Dominion's regulated gas and Virginia Power's regulated electric operations differs from the accounting for nonregulated operations in that they are required to reflect the effect of rate regulation in their Consolidated Financial Statements. For regulated businesses subject to federal or state cost-of-service rate regulation, regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by nonregulated companies. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, these costs that otherwise would be expensed by nonregulated companies are deferred as regulatory assets. Likewise, regulatory liabilities are recognized when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have yet to be incurred. Generally, regulatory assets and liabilities are amortized into income over the period authorized by the regulator.
The Companies evaluate whether or not recovery of their regulatory assets through future rates is probable and make various assumptions in their analyses. The expectations of future recovery are generally based on orders issued by regulatory commissions or historical experience, as well as discussions with applicable regulatory authorities. If recovery of a regulatory asset is determined to be less than probable, it will be written off in the period such assessment is made.
Asset Retirement Obligations
Dominion and Virginia Power recognize AROs at fair value as incurred or when sufficient information becomes available to
determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, the Companies evaluate the key assumptions underlying their AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion reports accretion of AROs and depreciation on asset retirement costs associated with its natural gas pipeline and storage well assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs. Virginia Power reports accretion of AROs and depreciation on asset retirement costs associated with decommissioning its nuclear power stations as an adjustment to the regulatory liability for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs is reported in other operations and maintenance expense and depreciation expense in the Consolidated Statements of Income.
Amortization of Debt Issuance Costs
Dominion and Virginia Power defer and amortize debt issuance costs and debt premiums or discounts over the expected lives of the respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. As permitted by regulatory authorities, gains or losses resulting from the refinancing of debt allocable to utility operations subject to cost-based rate regulation are deferred and amortized over the lives of the new issuances.
Investments
MARKETABLE EQUITY AND DEBT SECURITIES
Dominion accounts for and classifies investments in marketable equity and debt securities as trading or available-for-sale securities. Virginia Power classifies investments in marketable equity and debt securities as available-for-sale securities.
•	Trading securities include marketable equity and debt securities held by Dominion in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income.
•	Available-for-sale securities include all other marketable equity and debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power's nuclear decommissioning trusts are recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other available-for-sale securities, including those held in Dominion's merchant generation nuclear decommissioning trusts, net realized gains and losses (including any other-than-temporary impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax.
In determining realized gains and losses for marketable equity and debt securities, the cost basis of the security is based on the specific identification method.
NON-MARKETABLE INVESTMENTS
Dominion and Virginia Power account for illiquid and privately held securities for which market prices or quotations are not readily available under either the equity or cost method. Non-marketable investments include:
•	Equity method investments when Dominion and Virginia Power have the ability to exercise significant influence, but not control, over the investee. Dominion's investments are included in investments in equity method affiliates and Virginia Power's investments are included in other investments in their Consolidated Balance Sheets. Dominion and Virginia Power record equity method adjustments in other income in the Consolidated Statements of Income including: their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method.
•	Cost method investments when Dominion and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion's and Virginia Power's investments are included in other investments and nuclear decommissioning trust funds.
OTHER-THAN-TEMPORARY IMPAIRMENT
Dominion and Virginia Power periodically review their investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in fair value of any security is determined to be other-than-temporary, the security is written down to its fair value at the end of the reporting period.
Decommissioning Trust Investments-Special Considerations
•	The recognition provisions of the FASB's other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale or held-to-maturity, while the presentation and disclosure requirements apply to both debt and equity securities.
•	Debt Securities- Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion and Virginia Power record in earnings any unrealized loss for a debt security when the manager intends to sell the debt security or it is more-likely-than-not that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, the Companies record the credit loss in earnings and any remaining portion of the unrealized loss in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors.
•	Equity securities and other investments- Dominion's and Virginia Power's method of assessing other-than-temporary declines requires demonstrating the ability to hold individual securities for a period of time sufficient to allow for the anticipated recovery in their market value prior to the consideration of the other criteria mentioned above. Since the Companies have limited ability to oversee the day-to-day management of nuclear decommissioning trust fund investments, they do not have the ability to ensure investments are held through an anticipated recovery period. Accordingly, they consider all equity and other securities as well as non-marketable investments held in nuclear decommissioning trusts with market values below their cost bases to be other-than-temporarily impaired.
Inventories
Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory used in East Ohio gas distribution operations is valued using the LIFO method. Under the LIFO method, stored gas inventory was valued at $7 million and $24 million at December 31, 2013 and December 31, 2012, respectively. Based on the average price of gas purchased during 2013 and 2012, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by approximately $77 million and $69 million, respectively. Stored gas inventory held by Hope and certain nonregulated gas operations is valued using the weighted-average cost method.
Gas Imbalances
Natural gas imbalances occur when the physical amount of natural gas delivered from, or received by, a pipeline system or storage facility differs from the contractual amount of natural gas delivered or received. Dominion values these imbalances due to, or from, shippers and operators at an appropriate index price at period end, subject to the terms of its tariff for regulated entities. Imbalances are primarily settled in-kind. Imbalances due to Dominion from other parties are reported in other current assets and imbalances that Dominion owes to other parties are reported in other current liabilities in the Consolidated Balance Sheets.
Goodwill
Dominion evaluates goodwill for impairment annually as of April 1 and whenever an event occurs or circumstances change in the interim that would more-likely-than-not reduce the fair value of a reporting unit below its carrying amount.

Dispositions

Dispositions	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Dispositions	'
	DISPOSITIONS
	Sale of Illinois Gas Contracts
	In June 2013, Dominion completed the sale of Illinois Gas Contracts. The sales price was approximately $32 million, subject to post-closing adjustments. The sale resulted in a gain of approximately $29 million ($18 million after-tax) net of a $3 million write-off of goodwill, and is included in other operations and maintenance expense in Dominion's Consolidated Statement of Income. The sale of Illinois Gas Contracts did not qualify for discontinued operations classification as it is not considered a component under applicable accounting guidance.
	Sale of Brayton Point, Kincaid and Equity Method Investment in Elwood
	In March 2013, Dominion entered into an agreement with Energy Capital Partners to sell Brayton Point, Kincaid, and its equity method investment in Elwood.
	In the first and second quarters of 2013, Brayton Point's and Kincaid's assets and liabilities to be disposed were classified as held for sale and adjusted to their estimated fair value less cost to sell, resulting in impairment charges totaling $48 million ($28 million after-tax), which are included in discontinued operations in Dominion's Consolidated Statements of Income. In both periods, Dominion used the market approach to estimate the fair value of Brayton Point's and Kincaid's long-lived assets. These were considered Level 2 fair value measurements given that they were based on the agreed-upon sales price.
	Dominion's 50% interest in Elwood was an equity method investment and therefore, in accordance with applicable accounting guidance, the carrying amount of this investment was not classified as held for sale nor were the equity earnings from this investment reported as discontinued operations.
	In August 2013, Dominion completed the sale and received proceeds of approximately $465 million, net of transaction costs. The sale resulted in a $35 million ($25 million after-tax) gain attributable to its equity method investment in Elwood, which is included in other income in Dominion's Consolidated Statement of Income, which was partially offset by a $17 million ($18 million after-tax) loss attributable to Brayton Point and Kincaid, which includes a $16 million write-off of goodwill and is reflected in loss from discontinued operations in Dominion's Consolidated Statement of Income. See Note 6 for other impairments related to these power stations.
	The following table presents selected information regarding the results of operations of Brayton Point and Kincaid, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
	Year Ended December 31,	2013				2012				2011
	(millions)
	Operating revenue	$	304			$	258			$	380
	Loss before income taxes	(135		)	(1)	(1,768		)	(2)	(57		)
	(1) Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013. See Note 17 for more information.
	(2) Includes a long-lived asset impairment charge of $1.6 billion.
	Sale of Salem Harbor and State Line
	In August 2012, Dominion completed the sale of Salem Harbor. In the second quarter of 2012, the assets and liabilities to be disposed were classified as held for sale and adjusted to their estimated fair value less cost to sell. Also during the second quarter of 2012, Dominion completed the sale of State Line, which ceased operations in March 2012. See Note 6 for impairments related to these power stations.
	The following table presents selected information regarding the results of operations of Salem Harbor and State Line, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
	Year Ended December 31,	2012			2011
	(millions)
	Operating revenue	$	57		$	233
	Loss before income taxes(1)	(49		)	(34		)
	-1	Includes long-lived asset impairment charges of $55 million in 2011.

Operating_Revenue

Operating Revenue	12 Months Ended
	Dec. 31, 2013
Regulated and Unregulated Operating Revenue [Abstract]	'
Operating Revenue	'
	OPERATING REVENUE
	Dominion's and Virginia Power's operating revenue consists of the following:
	Year Ended December 31,	2013		2012		2011
	(millions)
	Dominion
	Electric sales:
	Regulated	$	7,193	$	7,102	$	7,114
	Nonregulated	2,511		2,483		2,721
	Gas sales:
	Regulated	323		250		287
	Nonregulated	930		1,071		1,634
	Gas transportation and storage	1,535		1,401		1,506
	Other	628		528		503
	Total operating revenue	$	13,120	$	12,835	$	13,765
	Virginia Power
	Regulated electric sales	$	7,193	$	7,102	$	7,114
	Other	102		124		132
	Total operating revenue	$	7,295	$	7,226	$	7,246

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	INCOME TAXES
	Judgment and the use of estimates are required in developing the provision for income taxes and reporting of tax-related assets and liabilities. The interpretation of tax laws involves uncertainty, since tax authorities may interpret the laws differently. Dominion and Virginia Power are routinely audited by federal and state tax authorities. Ultimate resolution of income tax matters may result in favorable or unfavorable impacts to net income and cash flows, and adjustments to tax-related assets and liabilities could be material.
	On January 2, 2013, U.S. federal legislation was enacted that provides an extension of the 50% bonus depreciation allowance for qualifying capital expenditures incurred through 2013.
	In September 2013, the IRS issued final regulations that provide guidance to taxpayers on the treatment of amounts paid to acquire, produce or improve tangible property, including whether expenditures should be deducted as repairs or capitalized and depreciated on tax returns. The final regulations include a number of safe harbor tax accounting methods which a taxpayer may choose to elect and, if adopted, will not be challenged by the IRS. In addition, the IRS reissued certain temporary regulations that were also issued concurrently as proposed regulations regarding property dispositions. The final regulations are effective for tax years beginning on or after January 1, 2014.  Although changes in tax accounting methods would be effective prospectively, implementation of certain changes will require a calculation of the cumulative effect of the change on prior years. Under IRS procedural guidance issued in January 2014, if such cumulative effect increases taxable income, it is includible in taxable income over a four-year period, beginning with the year of the change. However, if such cumulative effect decreases taxable income, the entire amount is includible in taxable income in the year of the change.
	Dominion and Virginia Power have evaluated tax accounting method changes that may be elected or required by the final regulations. At December 31, 2013, $17 million of deferred tax liabilities have been classified as current in the Companies’ Consolidated Balance Sheets, representing cumulative adjustment amounts expected to be reflected in income for tax purposes during the twelve months ending December 31, 2014. Tax accounting method changes in 2014 are not expected to materially affect the Companies’ cash flows, results of operations or financial condition.
	Continuing Operations
	Details of income tax expense for continuing operations including noncontrolling interests were as follows:
		Dominion(1)									Virginia Power(2)
	Year Ended December 31,	2013			2012			2011			2013			2012			2011
	(millions)
	Current:
	Federal	$	317		$	43		$	31		$	357		$	70		$	(35	)
	State	110			84			16			62			81			79
	Total current expense	427			127			47			419			151			44
	Deferred:
	Federal	497			645			685			224			482			484
	State	(31		)	40			48			17			21			13
	Total deferred expense	466			685			733			241			503			497
	Amortization of deferred investment tax credits	(1		)	(1		)	(2		)	(1		)	(1		)	(1		)
	Total income tax expense	$	892		$	811		$	778		$	659		$	653		$	540
	-1	In 2012, Dominion’s current federal income tax expense for continuing and discontinued operations includes a $195 million benefit related to a carryback of its 2012 net operating loss. In 2011, Dominion’s deferred federal income tax expense includes the recognition of a $346 million benefit, including $51 million related to discontinued operations, for its 2011 net operating loss expected to be used to reduce taxable income in future years.
	-2	In 2011, Virginia Power’s deferred federal income tax expense includes a $54 million benefit related to a portion of its 2011 net operating loss that is expected to be used in future years. Also, Virginia Power’s current federal income tax expense reflects the amounts of its 2011 net operating losses realized through its participation in a tax sharing agreement with Dominion and its subsidiaries.
	For continuing operations including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to Dominion's and Virginia Power's effective income tax rate as follows:
		Dominion						Virginia Power
	Year Ended December 31,	2013		2012		2011		2013		2012		2011
	U.S. statutory rate	35	%	35	%	35	%	35	%	35	%	35	%
	Increases (reductions) resulting from:
	State taxes, net of federal benefit	2.1		4.2		1.9		3.1		3.9		4.4
	Valuation allowances	(0.1	)	(0.7	)	—		—		—		—
	Investment and production tax credits	(2.4	)	(0.5	)	(0.6	)	(0.2	)	—		—
	AFUDC - equity	(0.6	)	(0.9	)	(0.6	)	(0.8	)	(0.9	)	(0.8	)
	Employee stock ownership plan deduction	(0.6	)	(0.7	)	(0.6	)	—		—		—
	Other, net	(0.4	)	(0.6	)	(0.7	)	(0.4	)	0.3		1.1
	Effective tax rate	33	%	35.8	%	34.4	%	36.7	%	38.3	%	39.7	%
	Dominion's effective tax rate in 2012 reflects a $20 million reduction of a valuation allowance related to state operating loss carryforwards attributable to Fairless. After considering the results of Fairless’ operations in recent years and a forecast of future operating results reflecting Dominion’s planned purchase of the facility, Dominion concluded that it was more likely than not that the tax benefit of the operating losses would be realized. Dominion acquired Fairless in 2013 and will continue to evaluate the likelihood of realizing these tax benefits on a quarterly basis.
	The Companies' deferred income taxes consist of the following:
		Dominion						Virginia Power
	At December 31,	2013			2012			2013			2012
	(millions)
	Deferred income taxes:
	Total deferred income tax assets	$	2,142		$	2,505		$	462		$	466
	Total deferred income tax liabilities	8,463			7,716			4,498			4,238
	Total net deferred income tax liabilities	$	6,321		$	5,211		$	4,036		$	3,772
	Total deferred income taxes:
	Plant and equipment, primarily depreciation method and basis differences	$	5,383		$	4,601		$	3,628		$	3,394
	Nuclear decommissioning	1,136			994			441			407
	Deferred state income taxes	606			474			285			265
	Federal benefit of deferred state income taxes	(212		)	(166		)	(100		)	(93		)
	Deferred fuel, purchased energy and gas costs	(33		)	3			(50		)	(16		)
	Pension benefits	435			231			(52		)	(17		)
	Other postretirement benefits	(78		)	(171		)	(3		)	(7		)
	Loss and credit carryforwards	(797		)	(656		)	(106		)	(77		)
	Valuation allowances	69			93			—			—
	Partnership basis differences	125			174			—			—
	Other	(313		)	(366		)	(7		)	(84		)
	Total net deferred income tax liabilities	$	6,321		$	5,211		$	4,036		$	3,772
	At December 31, 2013, Dominion had the following deductible loss and credit carryforwards:
	•	Federal loss carryforwards of $1.2 billion that expire if unutilized during the period 2021 through 2033;
	•	Federal investment tax credits of $58 million that expire if unutilized through 2033;
	•	Federal production and other tax credits of $45 million that expire if unutilized during the period 2031 through 2033;
	•	State loss carryforwards of $1.5 billion that expire if unutilized during the period 2014 through 2033. A valuation allowance on $763 million of these carryforwards has been established;
	•	State minimum tax credits of $133 million that do not expire; and
	•	State investment tax credits of $7 million that expire if unutilized through 2017.
At December 31, 2013, Virginia Power had the following deductible loss and credit carryforwards:
•	Federal loss carryforwards of $282 million that expire if unutilized during the period 2031 through 2033;
•	Federal production and other tax credits of $5 million that expire if unutilized during the period 2031 through 2033; and
•	State loss carryforwards of $2 million that expire if unutilized during the period 2031 through 2033.
A reconciliation of changes in the Companies' unrecognized tax benefits follows:
	Dominion									Virginia Power
	2013			2012			2011			2013			2012			2011
(millions)
Balance at January 1	$	293		$	347		$	307		$	57		$	114		$	117
Increases-prior period positions	17			28			127			12			4			22
Decreases-prior period positions	(99		)	(106		)	(119		)	(42		)	(80		)	(51		)
Increases-current period positions	30			43			64			14			24			47
Decreases-current period positions	(5		)	—			(21		)	—			—			(21		)
Settlements with tax authorities	(2		)	(4		)	—			(2		)	(4		)	—
Expiration of statutes of limitations	(12		)	(15		)	(11		)	—			(1		)	—
Balance at December 31	$	222		$	293		$	347		$	39		$	57		$	114
Certain unrecognized tax benefits, or portions thereof, if recognized, would affect the effective tax rate. Changes in these unrecognized tax benefits may result from remeasurement of amounts expected to be realized, settlements with tax authorities and expiration of statutes of limitations. For Dominion and its subsidiaries, these unrecognized tax benefits were $126 million, $167 million and $184 million at December 31, 2013, 2012 and 2011, respectively. For Dominion, the change in these unrecognized tax benefits decreased income tax expense by $29 million in 2013 and increased income tax expense by $1 million and $51 million in 2012 and 2011, respectively. For Virginia Power, these unrecognized tax benefits were $8 million, $13 million and $20 million at December 31, 2013, 2012 and 2011, respectively. For Virginia Power, the change in these unrecognized tax benefits increased income tax expense by $4 million, $1 million and $6 million in 2013, 2012 and 2011, respectively.
In January 2012, the Appellate Division of the IRS informed Dominion that the Joint Committee had completed its review of the settlement of tax years 2004 and 2005 for Dominion and its consolidated subsidiaries. Since the measurement of unrecognized tax benefits in 2011 considered the results of completed settlement negotiations, Dominion’s results of operations in 2012 were not affected.
In April 2012, the IRS issued its Revenue Agent Report for Dominion’s consolidated tax returns for tax years 2006 and 2007, reflecting the resolution of all issues except one that was subsequently settled in 2012.
The IRS examination of tax years 2008, 2009 and 2010 began in the first quarter of 2012 and was later expanded to include the examination of the 2011 tax year. The audit concluded in late 2013, resulting in a payment of $46 million. However, the amount of a refund previously received by Dominion for its carryback of 2008 losses to 2007 was adjusted. The loss carryback, as adjusted, has been submitted to the Joint Committee for review. Dominion anticipates resolution of this matter early in 2014 with no further adjustments. Accordingly, except for 2007 and 2008, the earliest tax year remaining open for examination of Dominion’s federal tax returns is 2012.
Effective for its 2014 tax year, Dominion has been accepted into the CAP. The CAP is a method of identifying and resolving tax issues through open, cooperative, and transparent interaction between the IRS and taxpayers prior to the filing of a return. Through the CAP, Dominion will have the opportunity to resolve complex tax matters with the IRS before filing its federal income tax returns, thus achieving certainty for such tax return filing positions accepted by the IRS. Under a Pre-CAP plan, the IRS audit of tax years 2012 and 2013 will begin in early 2014.
With the audit protection afforded tax accounting method changes implemented under the September 2013 IRS regulations, settlement negotiations and expiration of statutes of limitations, it is reasonably possible that unrecognized tax benefits could decrease in 2014 by up to $115 million for Dominion and up to $25 million for Virginia Power. If such changes were to occur, other than revisions of the accrual for interest on tax underpayments and overpayments, earnings could increase by up to $65 million for Dominion and $7 million for Virginia Power.
Otherwise, with regard to 2013 and prior years, Dominion and Virginia Power cannot estimate the range of reasonably possible changes to unrecognized tax benefits that may occur in 2014.
For each of the major states in which Dominion operates, the earliest tax year remaining open for examination is as follows:
State	Earliest
	Open Tax
	Year
Pennsylvania	2010
Connecticut	2010
Massachusetts	2008
Virginia(1)	2010
West Virginia	2010
-1	Virginia is the only state considered major for Virginia Power's operations.
Dominion and Virginia Power are also obligated to report adjustments resulting from IRS settlements to state tax authorities. In addition, if Dominion utilizes operating losses or tax credits generated in years for which the statute of limitations has expired, such amounts are subject to examination.
Discontinued Operations
Details of income tax expense for discontinued operations were as follows:
	Dominion
Year Ended December 31,	2013		2012		2011
(millions)
Current:
Federal	(274	)	(248	)	(41	)
State	(41	)	(6	)	(17	)
Total current benefit	(315	)	(254	)	(58	)
Deferred:
Federal	232		(368	)	10
State	40		(70	)	15
Total deferred expense (benefit)	272		(438	)	25
Total income tax benefit	(43	)	(692	)	(33	)
Dominion's effective tax rate for 2013 reflects the impact of goodwill written off in the sale of Kincaid and Brayton Point that is not deductible for tax purposes.
Dominion's effective tax rate for 2011 reflects an expectation that State Line's deferred tax assets, including 2011 operating losses, will not be realized in State Line's separately filed state tax returns.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	FAIR VALUE MEASUREMENTS
	Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. However, the use of a mid-market pricing convention (the mid-point between bid and ask prices) is permitted. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes not only the credit standing of counterparties involved and the impact of credit enhancements but also the impact of Dominion's and Virginia Power's own nonperformance risk on their liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability (the market with the most volume and activity for the asset or liability from the perspective of the reporting entity), or in the absence of a principal market, the most advantageous market for the asset or liability (the market in which the reporting entity would be able to maximize the amount received or minimize the amount paid). Dominion and Virginia Power apply fair value measurements to certain assets and liabilities including commodity and interest rate derivative instruments, and nuclear decommissioning trust and other investments including those held in Dominion's rabbi, pension and other postretirement benefit plan trusts, in accordance with the requirements described above. The Companies apply credit adjustments to their derivative fair values in accordance with the requirements described above. These credit adjustments are currently not material to the derivative fair values.
	Inputs and Assumptions
	The Companies maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. Fair value is based on actively-quoted market prices, if available. In the absence of actively-quoted market prices, price information is sought from external sources, including broker quotes and industry publications. When evaluating pricing information provided by brokers and other pricing services, they consider whether the broker is willing and able to trade at the quoted price, if the broker quotes are based on an active market or an inactive market and the extent to which brokers are utilizing a particular model if pricing is not readily available. If pricing information from external sources is not available, or if the Companies believe that observable pricing is not indicative of fair value, judgment is required to develop the estimates of fair value. In those cases they must estimate prices based on available historical and near-term future price information and certain statistical methods, including regression analysis, that reflect their market assumptions.
	Dominion's and Virginia Power's commodity derivative valuations are prepared by the ERM department. The ERM department reports directly to the Companies' CFO. The ERM department creates daily mark-to-market valuations for the Companies' derivative transactions using computer-based statistical models. The inputs that go into the market valuations are transactional information stored in the systems of record and market pricing information that resides in data warehouse databases. The majority of forward prices are automatically uploaded into the data warehouse databases from various third-party sources. Inputs obtained from third-party sources are evaluated for reliability considering the reputation, independence, market presence, and methodology used by the third-party. If forward prices are not available from third-party sources, then the ERM department models the forward prices based on other available market data. A team consisting of risk management and risk quantitative analysts meets each business day to assess the validity of market prices and mark-to-market valuations. During this meeting, the changes in mark-to-market valuations from period to period are examined and qualified against historical expectations. If any discrepancies are identified during this process, the mark-to-market valuations or the market pricing information is evaluated further and adjusted, if necessary.
	For options and contracts with option-like characteristics where observable pricing information is not available from external sources, the Companies generally use a modified Black-Scholes Model that considers time value, the volatility of the underlying commodities and other relevant assumptions when estimating fair value. The Companies use other option models under special circumstances, including a Spread Approximation Model when contracts include different commodities or commodity locations and a Swing Option Model when contracts allow either the buyer or seller the ability to exercise within a range of quantities. For contracts with unique characteristics, the Companies may estimate fair value using a discounted cash flow approach deemed appropriate in the circumstances and applied consistently from period to period. For individual contracts, the use of different valuation models or assumptions could have a significant effect on the contract's estimated fair value.
	The inputs and assumptions used in measuring fair value include the following:
	For commodity and foreign currency derivative contracts:
	•	Forward commodity prices
	•	Forward foreign currency prices
	•	Transaction prices
	•	Price volatility
	•	Price correlation
	•	Mean reversion
	•	Volumes
	•	Commodity location
	•	Load shaping
	•	Usage factors
	•	Interest rates
	•	Credit quality of counterparties and Dominion and Virginia Power
	•	Credit enhancements
	•	Time value
	For interest rate derivative contracts:
	•	Interest rate curves
	•	Credit quality of counterparties and Dominion and Virginia Power
	•	Volumes
	•	Credit enhancements
	•	Time value
	For investments:
	•	Quoted securities prices and indices
	•	Securities trading information including volume and restrictions
	•	Maturity
	•	Interest rates
	•	Credit quality
	•	NAV (for alternative investments and common/collective trust funds)
	Dominion and Virginia Power regularly evaluate and validate the inputs used to estimate fair value by a number of methods, including review and verification of models, as well as various market price verification procedures such as the use of pricing services and multiple broker quotes to support the market price of the various commodities and investments in which the Companies transact.
	Levels
	The Companies also utilize the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:
	•Level 1-Quoted prices (unadjusted) in active markets for identical assets and liabilities that they have the ability to access at the measurement date. Instruments categorized in Level 1 primarily consist of financial instruments such as the majority of exchange-traded derivatives, and exchange-listed equities, mutual funds and certain Treasury securities held in nuclear decommissioning trust funds for Dominion and Virginia Power and rabbi and benefit plan trust funds for Dominion.
	•Level 2-Inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for the asset or liability, including quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities in inactive markets, inputs other than quoted prices that are observable for the asset or liability, and inputs that are derived from observable market data by correlation or other means. Instruments categorized in Level 2 primarily include non-exchange traded derivatives such as over-the-counter commodity forwards and swaps, interest rate swaps, foreign currency forwards and options, restricted cash equivalents, and certain Treasury securities, money market funds, common/collective trust funds, and corporate, state and municipal debt securities held in nuclear decommissioning trust funds for Dominion and Virginia Power and rabbi and benefit plan trust funds for Dominion.
	•Level 3-Unobservable inputs for the asset or liability, including situations where there is little, if any, market activity for the asset or liability. Instruments categorized in Level 3 for Dominion and Virginia Power consist of long-dated commodity derivatives, FTRs and other modeled commodity derivatives. Additional instruments categorized in Level 3 for Dominion include NGLs and natural gas peaking options and alternative investments, consisting of investments in partnerships, joint ventures and other alternative investments, held in benefit plan trust funds.
	The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability.
	For derivative contracts, Dominion and Virginia Power recognize transfers among Level 1, Level 2 and Level 3 based on fair values as of the first day of the month in which the transfer occurs. Transfers out of Level 3 represent assets and liabilities that were previously classified as Level 3 for which the inputs became observable for classification in either Level 1 or Level 2. Because the activity and liquidity of commodity markets vary substantially between regions and time periods, the availability of observable inputs for substantially the full term and value of the Companies' over-the-counter derivative contracts is subject to change.
	Level 3 Valuations
	Fair value measurements are categorized as Level 3 when a significant amount of price or other inputs that are considered to be unobservable are used in their valuations. Long-dated commodity derivatives are generally based on unobservable inputs due to the length of time to settlement and the absence of market activity and are therefore categorized as Level 3. For NGL derivatives, market illiquidity requires a valuation based on proxy markets that do not always correlate to the actual instrument, therefore they are categorized as Level 3. FTRs are categorized as Level 3 fair value measurements because the only relevant pricing available comes from ISO auctions, which are generally not considered to be liquid markets. Other modeled commodity derivatives have unobservable inputs in their valuation, mostly due to non-transparent and illiquid markets. Alternative investments are categorized as Level 3 due to the absence of quoted market prices, illiquidity and the long-term nature of these assets. These investments are generally valued using NAV based on the proportionate share of the fair value as determined by reference to the most recent audited fair value financial statements or fair value statements provided by the investment manager adjusted for any significant events occurring between the investment manager's and the Companies' measurement date.
	Dominion and Virginia Power enter into certain physical and financial forwards and futures, options, and full requirements contracts, which are considered Level 3 as they have one or more inputs that are not observable and are significant to the valuation. The discounted cash flow method is used to value Level 3 physical and financial forwards, futures, and full requirements contracts. 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. Full requirements contracts add load shaping and usage factors in addition to the discounted cash flow model inputs. An option model is used to value Level 3 physical and financial options. 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, price correlations, mean reversion speeds, the original sales prices, and volumes. For Level 3 fair value measurements, the forward market prices, the implied price volatilities, price correlations, load shaping, mean reversion speeds, and usage factors 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 and Virginia Power's quantitative information about Level 3 fair value measurements. The range and weighted average are presented in dollars for market price inputs, years for mean reversion speeds, and percentages for price volatility, price correlations, load shaping, and usage factors.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range		Weighted Average(1)
	At December 31, 2013
	Assets:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	14		Discounted Cash Flow	Market Price (per Dth)	(5)	(2) - 5		2
	FTRs (3)	2			Discounted Cash Flow	Market Price (per MWh)	(5)	(1) - 5		—
	Liquids(4)	6			Discounted Cash Flow	Market Price (per Gal)	(5)	3-Jan		1
	Physical and Financial Options:
	Natural Gas(2)	4			Option Model	Market Price (per Dth)	(5)	5-Mar		4
						Price Volatility	(6)	14% - 36%		20	%
						Price Correlation	(7)	(9%) - 100%		36	%
						Mean Reversion	(8)	.01 - 1		0.53
	Full Requirements Contracts:
	Electricity	6			Discounted Cash Flow	Market Price (per MWh)	(5)	10 - 406	(11)	42
						Load Shaping	(9)	0% - 10%		7	%
						Usage Factor	(10)	11% - 29%		16	%
Total assets	$	32
Liabilities:
Physical and Financial Forwards and Futures:
Natural Gas(2)	$	19		Discounted Cash Flow	Market Price (per Dth)	(5)	(2) - 30		1
Electricity	1			Discounted Cash Flow	Market Price (per MWh)	(5)	28 - 240	(11)	39
FTRs(3)	9			Discounted Cash Flow	Market Price (per MWh)	(5)	(1) - 5		1
Liquids(4)	11			Discounted Cash Flow	Market Price (per Gal)	(5)	3-Jan		1
Physical and Financial Options:
Natural Gas(2)	8			Option Model	Market Price (per Dth)	(5)	11-Mar		7
					Price Volatility	(6)	14% - 36%		20	%
					Price Correlation	(7)	(9%) - 100%		36	%
					Mean Reversion	(8)	.01-1		0.53
Total liabilities	$	48
-1	Averages weighted by volume.
-2	Includes basis.
-3	Information represents Virginia Power's quantitative information about Level 3 fair value measurements.
-4	Includes NGLs.
-5	Represents market prices beyond defined terms for Levels 1 and 2.
-6	Represents volatilities unrepresented in published markets.
-7	Represents intra-price correlations for which markets do not exist.
-8	Represents mean-reverting property in price simulation modeling.
-9	Converts block monthly loads to 24-hour load shapes.
-10	Represents expected increase (decrease) in sales volumes compared to historical usage.
-11	The range in market prices is the result of large variability in hourly power prices during peak and off-peak hours.
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)
Price Correlation	Buy	Increase (decrease)	Loss (gain)
Price Correlation	Sell	Increase (decrease)	Gain (loss)
Load Shaping	Sell(1)	Increase (decrease)	Loss (gain)
Usage Factor	Sell(2)	Increase (decrease)	Gain (loss)
Mean Reversion	Buy	Increase (decrease)	Loss (gain)
Mean Reversion	Sell	Increase (decrease)	Gain (loss)
-1	Assumes the contract is in a gain position and load increases during peak hours.
-2	Assumes the contract is in a gain position.
Nonrecurring Fair Value Measurements
Natural Gas Facilities
In June 2013, Dominion purchased certain natural gas infrastructure facilities that were previously leased from third parties. The purchase price was based on terms in the lease, which exceeded current market pricing. As a result of the purchase price and expected losses, Dominion recorded an impairment charge of $49 million ($29 million after-tax) in other operations and maintenance expense in its Consolidated Statements of Income, to write down the long-lived assets to their estimated fair values of less than $1 million. As management was not aware of any recent market transactions for comparable assets with sufficient transparency to develop a market approach to fair value, Dominion used the income approach (discounted cash flows) to estimate the fair value of the assets in this impairment test. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs, including estimates of future production and other commodity prices.
MERCHANT POWER STATIONS
In the third quarter of 2012, Dominion decided to pursue the sale of Brayton Point and Kincaid, as well as its 50% interest in Elwood, which is an equity method investment. Since Dominion was unlikely to operate the Brayton Point and Kincaid facilities through their estimated useful lives, Dominion evaluated these power stations for recoverability under a probability weighted approach and concluded that the carrying values of these facilities were not impaired as of September 30, 2012.
At December 31, 2012, Dominion updated its recoverability analysis for Brayton Point and Kincaid to reflect bids received and an updated probability weighting. As a result of this updated evaluation, Dominion recorded an impairment charge of approximately $1.6 billion ($1.0 billion after-tax), which is included in loss from discontinued operations in its Consolidated Statement of Income, to write down Brayton Point’s and Kincaid's long-lived assets to their estimated fair value of approximately $216 million. Dominion used a market approach to estimate the fair value of Brayton Point’s and Kincaid's long-lived assets. This was considered a Level 2 fair value measurement given it was based on bids received.
See Note 3 for information regarding the sale of Brayton Point, Kincaid and Dominion's equity method investment in Elwood, including an additional impairment.
In April 2011, Dominion announced it would pursue a sale of Kewaunee since it was not able to move forward with its original plan to grow its nuclear fleet in the Midwest to take advantage of economies of scale. Dominion was unable to find a buyer for the facility. In addition, the power purchase agreements for the two utilities that contracted to buy Kewaunee's generation expired in December 2013 at a time of low wholesale electricity prices in the region. At September 30, 2012, Dominion expected that it would permanently cease generation operations at Kewaunee in 2013 and commence decommissioning of the facility. As a result, Dominion evaluated Kewaunee for impairment since it was more likely than not that Kewaunee would be retired before the end of its previously estimated useful life. As management was not aware of any recent market transactions for comparable assets with sufficient transparency to develop a market approach to fair value, Dominion used the income approach (discounted cash flows) to estimate the fair value of Kewaunee's long-lived assets. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs including estimates of future power and other commodity prices.
As a result of this evaluation in September 2012, Dominion recorded impairment and other charges of $435 million ($281 million after-tax) largely reflected in other operations and maintenance expense in its Consolidated Statement of Income. This primarily reflects a $378 million ($244 million after-tax) charge for the full impairment of Kewaunee's long-lived assets, a write down of materials and supplies inventories of $33 million ($21 million after-tax), and a $24 million ($16 million after-tax) charge related to severance costs.
The decision to decommission Kewaunee was approved by Dominion's Board of Directors in October 2012 after consideration of the factors discussed above, which made it uneconomic for Kewaunee to continue operations. Kewaunee ceased operations and decommissioning activities commenced in May 2013.
During March 2011, Dominion determined that it was unlikely that State Line would participate in the May 2011 PJM capacity base residual auction that would commit State Line's capacity from June 2014 through May 2015. This determination reflected an expectation that margins for coal-fired generation will remain compressed in the 2014 and 2015 period in combination with the expectation that State Line may be impacted during the same time period by environmental regulations that would likely require significant capital expenditures. As a result, Dominion evaluated State Line for impairment since it was more likely than not that State Line would be retired before the end of its previously estimated useful life. As a result of this evaluation, Dominion recorded an impairment charge of $55 million ($39 million after-tax), which is now reflected in loss from discontinued operations in its Consolidated Statement of Income, to write down State Line's long-lived assets to their estimated fair value of less than $1 million. State Line was retired in March 2012 and sold in the second quarter of 2012.
As management was not aware of any recent market transactions for comparable assets with sufficient transparency to develop a market approach to fair value, Dominion used the income approach (discounted cash flows) to estimate the fair value of State Line's long-lived assets. This was considered a Level 3 fair value measurement due to the use of significant unobservable inputs including estimates of future power and other commodity prices.
In the second quarter of 2012, an agreement was reached to sell Salem Harbor and the assets and liabilities to be disposed were classified as held for sale and adjusted to their estimated fair value less cost to sell. This resulted in a pre-tax charge of $27 million ($16 million after-tax), which is included in loss from discontinued operations in Dominion's Consolidated Statement of Income. This was considered a Level 2 fair value measurement as it was based on the negotiated sales price. Salem Harbor was sold in the third quarter of 2012.
EMISSIONS ALLOWANCES
In the third quarter of 2011, Dominion and Virginia Power evaluated their SO2 emissions allowances not expected to be consumed by generating units for potential impairment due to the EPA's issuance of CSAPR as discussed in Note 22. Prior to the issuance of CSAPR, Dominion and Virginia Power held $57 million and $43 million, respectively, of SO2 emissions allowances obtained for ARP and CAIR compliance. Due to CSAPR's establishment of a new allowance program and the elimination of CAIR, Dominion and Virginia Power had more SO2 emissions allowances than needed for ARP compliance. As a result of this evaluation, Dominion and Virginia Power recorded an impairment charge to write down these emissions allowances to their estimated fair value of less than $1 million. For Dominion, the $57 million ($34 million after-tax) charge was recorded partially in other operations and maintenance expense ($43 million, $26 million after-tax) and partially in loss from discontinued operations ($14 million, $8 million after-tax) in its Consolidated Statement of Income. For Virginia Power, the $43 million ($26 million after-tax) charge was recorded in other operations and maintenance expense in its Consolidated Statement of Income.
To estimate the value of these emissions allowances, Dominion utilized a market approach by obtaining broker quotes to validate CSAPR's impact on emissions allowance prices. However, due to limited market activity for future SO2 vintage year allowances, this was considered a Level 3 fair value measurement.
Recurring Fair Value Measurements
Fair value measurements are separately disclosed by level within the fair value hierarchy with a separate reconciliation of fair value measurements categorized as Level 3. Fair value disclosures for assets held in Dominion's pension and other postretirement benefit plans are presented in Note 21.
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 December 31, 2013
Assets:
Derivatives:
Commodity	$	3		$	718		$	32		$	753
Interest rate	—			137			—			137
Investments(1):
Equity securities:
U.S.:
Large Cap	2,417			—			—			2,417
Other	79			—			—			79
Non-U.S.:
Large Cap	13			—			—			13
Fixed Income:
Corporate debt instruments	—			345			—			345
U.S. Treasury securities and agency debentures	415			175			—			590
State and municipal	—			343			—			343
Other	—			3			—			3
Cash equivalents and other	—			103			—			103
Restricted cash equivalents	—			8			—			8
Total assets	$	2,927		$	1,832		$	32		$	4,791
Liabilities:
Derivatives:
Commodity	$	3		$	1,051		$	48		$	1,102
Total liabilities	$	3		$	1,051		$	48		$	1,102
At December 31, 2012
Assets:
Derivatives:
Commodity	$	12		$	639		$	84		$	735
Interest rate	—			93			—			93
Investments(1):
Equity securities:
U.S.:
Large Cap	1,973			—			—			1,973
Other	59			—			—			59
Non-U.S.:
Large Cap	12			—			—			12
Fixed Income:
Corporate debt instruments	—			325			—			325
U.S. Treasury securities and agency debentures	391			152			—			543
State and municipal	—			315			—			315
Other	—			7			—			7
Cash equivalents and other	13			67			—			80
Restricted cash equivalents	—			33			—			33
Total assets	$	2,460		$	1,631		$	84		$	4,175
Liabilities:
Derivatives:
Commodity	$	8		$	528		$	59		$	595
Interest rate	—			66			—			66
Total liabilities	$	8		$	594		$	59		$	661
-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:
	2013			2012			2011
(millions)
Balance at January 1,	$	25		$	(71	)	$	(50	)
Total realized and unrealized gains (losses):
Included in earnings	(9		)	(15		)	(77		)
Included in other comprehensive income (loss)	1			101			14
Included in regulatory assets/liabilities	(9		)	30			(42		)
Settlements	(23		)	47			88
Transfers out of Level 3	(1		)	(67		)	(4		)
Balance at December 31,	$	(16	)	$	25		$	(71	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	$	—		$	42		$	22
The following table presents Dominion's gains and losses included in earnings in the Level 3 fair value category:
	Operating			Electric Fuel			Purchased			Total
	Revenue			and Energy			Gas
				Purchases
(millions)
Year Ended December 31, 2013
Total gains (losses) included in earnings	$	11		$	(19	)	$	(1	)	$	(9	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	1			—			(1		)	—
Year Ended December 31, 2012
Total gains (losses) included in earnings	$	35		$	(50	)	$	—		$	(15	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	42			—			—			42
Year Ended December 31, 2011
Total gains (losses) included in earnings	$	(32	)	$	(45	)	$	—		$	(77	)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	22			—			—			22
VIRGINIA POWER
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 December 31, 2013
Assets:
Derivatives:
Commodity	$	—		$	3		$	2		$	5
Interest rate	—			48			—			48
Investments(1):
Equity securities:
U.S.:
Large Cap	1,021			—			—			1,021
Other	36			—			—			36
Fixed Income:
Corporate debt instruments	—			191			—			191
U.S. Treasury securities and agency debentures	146			66			—			212
State and municipal	—			164			—			164
Cash equivalents and other	—			31			—			31
Restricted cash equivalents	—			8			—			8
Total assets	$	1,203		$	511		$	2		$	1,716
Liabilities:
Derivatives:
Commodity	$	—		$	3		$	9		$	12
Total Liabilities	$	—		$	3		$	9		$	12
At December 31, 2012
Assets:
Derivatives:
Commodity	$	—		$	1		$	5		$	6
Investments(1):
Equity securities:
U.S.:
Large Cap	779			—			—			779
Other	27			—			—			27
Fixed Income:
Corporate debt instruments	—			196			—			196
U.S. Treasury securities and agency debentures	168			66			—			234
State and municipal	—			118			—			118
Other	—			1			—			1
Cash equivalents and other	7			31			—			38
Restricted cash equivalents	—			10			—			10
Total assets	$	981		$	423		$	5		$	1,409
Liabilities:
Derivatives:
Commodity	$	—		$	6		$	3		$	9
Interest rate	—			25			—			25
Total Liabilities	$	—		$	31		$	3		$	34
-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:
	2013			2012			2011
(millions)
Balance at January 1,	$	2		$	(28	)	$	14
Total realized and unrealized gains (losses):
Included in earnings	(17		)	(50		)	(45		)
Included in regulatory assets/liabilities	(9		)	30			(42		)
Settlements	17			50			45
Balance at December 31,	$	(7	)	$	2		$	(28	)
The gains and losses included in earnings in the Level 3 fair value category, including any attributable to the change in unrealized gains and losses relating to assets still held at the reporting date, were classified in electric fuel and other energy-related purchases expense in Virginia Power's Consolidated Statements of Income for the years ended December 31, 2013, 2012 and 2011. There were no unrealized gains and losses included in earnings in the Level 3 fair value category relating to assets/liabilities still held at the reporting date for the years ended December 31, 2013, 2012 and 2011.
Fair Value of Financial Instruments
Substantially all of Dominion's and Virginia Power's financial instruments are recorded at fair value, with the exception of the instruments described below that 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, customer and other receivables, short-term debt and accounts payable are representative of fair value because of the short-term nature of these instruments. For Dominion's and Virginia Power's financial instruments that are not recorded at fair value, the carrying amounts and fair values are as follows:
At December 31,	2013						2012
	Carrying			Estimated			Carrying			Estimated
	Amount			Fair Value(1)			Amount			Fair Value(1)
(millions)
Dominion
Long-term debt, including securities due within one year(2)	$	18,396		$	19,887		$	16,841		$	19,898
Long-term debt, including securities due within one year - VIE(3)	—			—			860			864
Junior subordinated notes(3)	1,373			1,394			1,373			1,430
Remarketable subordinated notes(3)	1,080			1,192			—			—
Subsidiary preferred stock(4)	257			261			257			255
Virginia Power
Long-term debt, including securities due within one year(2)	$	8,032		$	8,897		$	6,669		$	8,270
Preferred stock(4)	257			261			257			255
-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 discount and premium. At December 31, 2013, and 2012, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of approximately $55 million and $93 million, respectively.
-3	Carrying amount includes amounts which represent the unamortized discount or premium.
-4	Includes deferred issuance expenses of $2 million at December 31, 2013 and 2012.

Derivatives_and_Hedge_Accounti

Derivatives and Hedge Accounting Activities	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives and Hedge Accounting Activities	'
	DERIVATIVES AND HEDGE ACCOUNTING ACTIVITIES
	Dominion and Virginia Power are exposed to the impact of market fluctuations in the price of electricity, natural gas and other energy-related products they market and purchase, as well as currency exchange and interest rate risks of their business operations. The Companies use derivative instruments to manage exposure to these risks, and designate certain derivative instruments as fair value or cash flow hedges for accounting purposes. As discussed in Note 2, for jurisdictions subject to cost-based rate regulation, changes in the fair value of derivatives are deferred as regulatory assets or regulatory liabilities until the related transactions impact earnings. See Note 6 for further information about fair value measurements and associated valuation methods for derivatives.
	Derivative assets and liabilities are presented gross on Dominion's and Virginia Power's Consolidated Balance Sheets. Dominion's and Virginia Power'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. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Exchange contracts utilize a financial intermediary, exchange, or clearinghouse to enter, execute, or clear the transactions. Certain over-the-counter and exchange contracts contain contractual rights of setoff through master netting arrangements, derivative clearing agreements, and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency, or other conditions.
	In general, most over-the-counter transactions and all exchange contracts are subject to collateral requirements. Types of collateral for over-the-counter and exchange contracts include cash, letters of credit, and in some cases other forms of security, none of which are subject to restrictions. Cash collateral is used in the table below to offset derivative assets and liabilities. Certain accounts receivable and accounts payable recognized on Dominion's and Virginia Power's 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
	The tables below present Dominion's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
		31-Dec-13									31-Dec-12
		Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	137		$	—		$	137		$	93	$	—	$	93
	Commodity contracts:
	Over-the-counter	240			—			240			290		—		290
	Exchange	506			—			506			416		—		416
	Total derivatives, subject to a master netting or similar arrangement	883			—			883			799		—		799
	Total derivatives, not subject to a master netting or similar arrangement	7			—			7			29		—		29
	Total(1)	$	890		$	—		$	890		$	828	$	—	$	828
	-1	At December 31, 2013, the total derivative asset balance contains $687 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $203 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
					31-Dec-13										31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet										Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	137		$	—		$	—		$	137	$	93	$	19	$	—	$	74
	Commodity contracts:
	Over-the-counter	240			63			—			177		290		97		—		193
	Exchange	506			505			—			1		416		350		4		62
	Total	$	883		$	568		$	—		$	315	$	799	$	466	$	4	$	329
		31-Dec-13									31-Dec-12
		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)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	66	$	—	$	66
	Commodity contracts:
	Over-the-counter	262			—			262			191		—		191
	Exchange	838			—			838			393		—		393
	Total derivatives, subject to a master netting or similar arrangement	1,100			—			1,100			650		—		650
	Total derivatives, not subject to a master netting or similar arrangement	2			—			2			11		—		11
	Total(1)	$	1,102		$	—		$	1,102		$	661	$	—	$	661
	-1	At December 31, 2013, the total derivative liability balance contains $828 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $274 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.
					31-Dec-13										31-Dec-12
					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)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	—	$	66	$	19	$	—	$	47
	Commodity contracts:
	Over-the-counter	262			63			69			130		191		97		20		74
	Exchange	838			505			333			—		393		350		43		—
	Total	$	1,100		$	568		$	402		$	130	$	650	$	466	$	63	$	121
	The following table presents the volume of Dominion's derivative activity as of December 31, 2013. 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)	116			19
	Basis(1)	466			281
	Electricity (MWh):
	Fixed price(1)	14,814,767			14,935,144
	FTRs	41,316,345			437,384
	Capacity (MW)	83,050			18,300
	Liquids (gallons)(2)	151,200,000			—
	Interest rate	$	2,050,000,000		$	750,000,000
	-1	Includes options.
	-2	Includes NGLs and oil.
For the years ended December 31, 2013, 2012 and 2011, 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 December 31, 2013:
	AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum
	After-Tax						Term
(millions)
Commodities:
Gas	$	(3	)	$	(3	)	28 months
Electricity	(172		)	(124		)	36 months
Other	(3		)	(3		)	29 months
Interest rate	(110		)	(7		)	364 months
Total	$	(288	)	$	(137	)
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 and interest rates.
Fair Value and Gains and Losses on Derivative Instruments
The following tables present the fair values of Dominion's derivatives and where they are presented in its Consolidated Balance Sheets:
	Fair Value  -			Fair Value -			Total
	Derivatives			Derivatives			Fair
	under			not under			Value
	Hedge			Hedge
	Accounting			Accounting
(millions)
At December 31, 2013
ASSETS
Current Assets
Commodity	$	49		$	522		$	571
Interest rate	116			—			116
Total current derivative assets	165			522			687
Noncurrent Assets
Commodity	28			154			182
Interest rate	21			—			21
Total noncurrent derivative assets(1)	49			154			203
Total derivative assets	$	214		$	676		$	890
LIABILITIES
Current Liabilities
Commodity	$	267		$	561		$	828
Total current derivative liabilities	267			561			828
Noncurrent Liabilities
Commodity	119			155			274
Total noncurrent derivative liabilities(2)	119			155			274
Total derivative liabilities	$	386		$	716		$	1,102
At December 31, 2012
ASSETS
Current Assets
Commodity	$	103		$	379		$	482
Interest rate	36			—			36
Total current derivative assets	139			379			518
Noncurrent Assets
Commodity	130			123			253
Interest rate	57			—			57
Total noncurrent derivative assets(1)	187			123			310
Total derivative assets	$	326		$	502		$	828
LIABILITIES
Current Liabilities
Commodity	$	103		$	341		$	444
Interest rate	66			—			66
Total current derivative liabilities	169			341			510
Noncurrent Liabilities
Commodity	58			93			151
Total noncurrent derivative liabilities(2)	58			93			151
Total derivative liabilities	$	227		$	434		$	661
-1	Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion's Consolidated Balance Sheets.
-2	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	Amount of			Amount of			Increase
relationships	Gain (Loss)			Gain (Loss)			(Decrease)
	Recognized			Reclassified			in
	in AOCI on			from AOCI			Derivatives
	Derivatives			to Income			Subject to
	(Effective						Regulatory
	Portion)(1)						Treatment(2)
(millions)
Year Ended December 31, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	(58	)
Purchased gas				(47		)
Electric fuel and other energy-related purchases				(10		)
Total commodity	$	(481	)	$	(115	)	$	5
Interest rate(3)	77			(15		)	81
Total	$	(404	)	$	(130	)	$	86
Year Ended December 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	188
Purchased gas				(75		)
Electric fuel and other energy-related purchases				(17		)
Total commodity	$	71		$	96		$	10
Interest rate(3)	(84		)	(2		)	(35		)
Total	$	(13	)	$	94		$	(25	)
Year Ended December 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue				$	153
Purchased gas				(78		)
Electric fuel and other energy-related purchases				(2		)
Purchased electric capacity				1
Total commodity	$	137		$	74		$	(20	)
Interest rate(3)	(252		)	(8		)	(143		)
Total	$	(115	)	$	66		$	(163	)
-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.
Derivatives not designated as hedging	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
instruments
Year Ended December 31,	2013			2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity:
Operating revenue	$	(45	)	$	168		$	111
Purchased gas	(9		)	(14		)	(35		)
Electric fuel and other energy-related purchases	(29		)	(40		)	(45		)
Interest rate(2)	—			17			(5		)
Total	$	(83	)	$	131		$	26
-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	Amounts recorded in Dominion's Consolidated Statements of Income are classified in interest and related charges.
VIRGINIA POWER
The tables below present Virginia Power's derivative asset and liability balances by type of financial instrument, before and after the effects of offsetting:
	31-Dec-13									31-Dec-12
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
(millions)
Interest rate contracts:
Over-the-counter	$	48		$	—		$	48		$	—	$	—	$	—
Commodity contracts:
Over-the-counter	4			—			4			6		—		6
Exchange	1			—			1			—		—		—
Total derivatives, subject to a master netting or similar arrangement	53			—			53			6		—		6
Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—		—		—
Total(1)	$	53		$	—		$	53		$	6	$	—	$	6
-1	At December 31, 2013, the total derivative asset balance contains $53 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $6 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet.
				31-Dec-13										31-Dec-12
				Gross Amounts Not Offset in the Consolidated Balance Sheet										Gross Amounts Not Offset in the Consolidated Balance Sheet
	Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
(millions)
Interest rate contracts:
Over-the-counter	$	48		$	—		$	—		$	48	$	—	$	—	$	—	$	—
Commodity contracts:
Over-the-counter	4			4			—			—		6		3		—		3
Exchange	1			—			—			1		—		—		—		—
Total	$	53		$	4		$	—		$	49	$	6	$	3	$	—	$	3
	31-Dec-13									31-Dec-12
	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)
Interest rate contracts:
Over-the-counter	$	—		$	—		$	—		$	25	$	—	$	25
Commodity contracts:
Over-the-counter	12			—			12			7		—		7
Exchange	—			—			—			2		—		2
Total derivatives, subject to a master netting or similar arrangement	12			—			12			34		—		34
Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—		—		—
Total(1)	$	12		$	—		$	12		$	34	$	—	$	34
-1	At December 31, 2013, the total derivative liability balance contains $12 million of current liabilities, which is presented in current derivative liabilities in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $33 million of current liabilities, which is presented in current derivative liabilities in Virginia Power’s Consolidated Balance Sheet and $1 million of noncurrent derivative liabilities, which is presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheet.
				31-Dec-13										31-Dec-12
				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)
Interest rate contracts:
Over-the-counter	$	—		$	—		$	—		$	—	$	25	$	—	$	—	$	25
Commodity contracts:
Over-the-counter	12			4			7			1		7		3		—		4
Exchange	—			—			—			—		2		—		2		—
Total	$	12		$	4		$	7		$	1	$	34	$	3	$	2	$	29
The following table presents the volume of Virginia Power's derivative activity at December 31, 2013. 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	15			—
Basis	7			—
Electricity (MWh):
Fixed price	624,800			—
FTRs	39,186,609			—
Capacity (MW)	75,500			18,300
Interest rate	$	600,000,000		$	—
For the years ended December 31, 2013, 2012 and 2011, 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 the time value of options and changes in the differences between spot prices and forward prices.
Fair Value and Gains and Losses on Derivative Instruments
The following tables present the fair values of Virginia Power's derivatives and where they are presented in its Consolidated Balance Sheets:
	Fair Value  -			Fair Value -			Total
	Derivatives			Derivatives			Fair
	under			not under			Value
	Hedge			Hedge
	Accounting			Accounting
(millions)
At December 31, 2013
ASSETS
Current Assets
Commodity	$	2		$	3		$	5
Interest rate	48						48
Total current derivative assets(1)	50			3			53
Total derivative assets	$	50		$	3		$	53
LIABILITIES
Current Liabilities
Commodity	$	1		$	11		$	12
Total current derivative liabilities	1			11			12
Total derivative liabilities	$	1		$	11		$	12
At December 31, 2012
ASSETS
Current Assets
Commodity	$	1		$	5		$	6
Total current derivative assets(1)	1			5			6
Total derivative assets	$	1		$	5		$	6
LIABILITIES
Current Liabilities
Commodity	$	5		$	3		$	8
Interest rate	25			—			25
Total current derivative liabilities	$	30		$	3		$	33
Noncurrent Liabilities
Commodity	1			—			1
Total noncurrent derivative liabilities(2)	1			—			1
Total derivative liabilities	$	31		$	3		$	34
-1	Current derivative assets are presented in other current assets in Virginia Power's Consolidated Balance Sheets.
-2	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	Amount of Gain			Amount of			Increase
relationships	(Loss)			Gain (Loss)			(Decrease) in
	Recognized in			Reclassified			Derivatives
	AOCI on			from AOCI to			Subject to
	Derivatives			Income			Regulatory
	(Effective						Treatment(2)
	Portion)(1)
(millions)
Year Ended December 31, 2013
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	—
Total commodity	$	—		$	—		$	5
Interest rate(3)	9			—			81
Total	$	9		$	—		$	86
Year Ended December 31, 2012
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(4	)
Total commodity	$	(2	)	$	(4	)	$	10
Interest rate(3)	(6		)	—			(35		)
Total	$	(8	)	$	(4	)	$	(25	)
Year Ended December 31, 2011
Derivative Type and Location of Gains (Losses)
Commodity:
Electric fuel and other energy-related purchases				$	(1	)
Purchased electric capacity				1
Total commodity	$	(3	)	$	—		$	(20	)
Interest rate(3)	(6		)	1			(143		)
Total	$	(9	)	$	1		$	(163	)
-1	Amounts deferred into AOCI have no associated effect in Virginia Power's Consolidated Statements of Income.
-2	Represents net derivative activity deferred into and amortized out of regulatory assets/liabilities. Amounts deferred into regulatory assets/liabilities have no associated effect in Virginia Power's Consolidated Statements of Income.
-3	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in interest and related charges.
Derivatives not designated as hedging	Amount of Gain (Loss) Recognized
instruments	in Income on Derivatives(1)
Year Ended December 31,	2013			2012			2011
(millions)
Derivative Type and Location of Gains (Losses)
Commodity(2)	$	(16	)	$	(50	)	$	(45	)
Interest rate(3)	—			—			(5		)
Total	$	(16	)	$	(50	)	$	(50	)
-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.
-3	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in interest and related charges.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	EARNINGS PER SHARE
	The following table presents the calculation of Dominion's basic and diluted EPS:
		2013		2012		2011
	(millions, except EPS)
	Net income attributable to Dominion	$	1,697	$	302	$	1,408
	Average shares of common stock outstanding-Basic	578.7		572.9		573.1
	Net effect of dilutive securities(1)	0.8		1		1.5
	Average shares of common stock outstanding-Diluted	579.5		573.9		574.6
	Earnings Per Common Share-Basic	$	2.93	$	0.53	$	2.46
	Earnings Per Common Share-Diluted	$	2.93	$	0.53	$	2.45
	-1	Dilutive securities consist primarily of contingently convertible senior notes. See Note 17 for more information.
	Dominion's 2013 Series A Equity Units and 2013 Series B Equity Units issued in June 2013 are potentially dilutive securities but were excluded from the calculation of diluted EPS for the year ended December 31, 2013.  See Note 17 for more information. There were no potentially dilutive securities excluded from the calculation of diluted EPS for the years ended December 31, 2012 and 2011.

Investments

Investments	12 Months Ended
	Dec. 31, 2013
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 $107 million and $95 million at December 31, 2013 and 2012, respectively. Cost-method investments held in Dominion's rabbi trusts totaled $10 million and $14 million at December 31, 2013 and 2012, 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			Total			Total				Fair
		Cost			Unrealized			Unrealized				Value
					Gains (1)			Losses (1)
	(millions)
	2013
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,183		$	1,194		$	—			$	2,377
	Other	49			23			—				72
	Marketable debt securities:
	Corporate debt instruments	332			16			(3		)		345
	U.S. Treasury securities and agency debentures	589			8			(10		)		587
	State and municipal	297			11			(5		)		303
	Other	3			—			—				3
	Cost method investments	106			—			—				106
	Cash equivalents and other(2)	110			—			—				110
	Total	$	2,669		$	1,252		$	(18	)	(3)	$	3,903
	2012
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,210		$	732		$	—			$	1,942
	Other	40			13			—				53
	Marketable debt securities:
	Corporate debt instruments	295			30			—				325
	U.S. Treasury securities and agency debentures	523			19			(2		)		540
	State and municipal	248			26			—				274
	Other	6			1			—				7
	Cost method investments	117			—			—				117
	Cash equivalents and other(2)	72			—			—				72
	Total	$	2,511		$	821		$	(2	)	(3)	$	3,330
	-1	Included in AOCI and the decommissioning trust regulatory liability as discussed in Note 2.
	-2	Includes pending sales of securities of $11 million and pending purchases of securities of $6 million at December 31, 2013 and 2012, respectively.
	-3	The fair value of securities in an unrealized loss position was $604 million and $195 million at December 31, 2013 and 2012, respectively.
	The fair value of Dominion's marketable debt securities held in nuclear decommissioning trust funds at December 31, 2013 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	128
	Due after one year through five years	357
	Due after five years through ten years	362
	Due after ten years	391
	Total	$	1,238
	Presented below is selected information regarding Dominion's marketable equity and debt securities held in nuclear decommissioning trust funds:
	Year Ended December 31,	2013			2012			2011
	(millions)
	Proceeds from sales	$	1,476		$	1,356		$	1,757
	Realized gains(1)	157			98			79
	Realized losses(1)	33			33			92
	-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability as discussed in Note 2.
	Dominion recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows:
	Year Ended December 31,	2013			2012			2011
	(millions)
	Total other-than-temporary impairment losses(1)	$	31		$	26		$	75
	Losses recorded to decommissioning trust regulatory liability	(13		)	(10		)	(24		)
	Losses recognized in other comprehensive income (before taxes)	(10		)	(2		)	(3		)
	Net impairment losses recognized in earnings	$	8		$	14		$	48
	-1	Amounts include other-than-temporary impairment losses for debt securities of $18 million, $4 million and $6 million at December 31, 2013, 2012 and 2011, respectively.
Equity Method Investments
Investments that Dominion accounts for under the equity method of accounting are as follows:
Company	Ownership%		Investment Balance						Description
As of December 31,			2013			2012
(millions)
Blue Racer Midstream LLC	50	%	$	510		$	39		Midstream gas and related services
Fowler I Holdings LLC	50	%	149			158			Wind-powered merchant generation facility
NedPower Mount Storm LLC	50	%	131			137			Wind-powered merchant generation facility
Iroquois Gas Transmission System, LP	24.72	%	105			102			Gas transmission system
Elwood Energy LLC(1)	—	%	—			117			Natural gas-fired merchant generation peaking facility
Other(2)	various		21			5
Total			$	916		$	558
(1) Following the 2013 sale of Elwood, at December 31, 2013, Dominion retained a 0.5% cost method investment. At December 31, 2012, Dominion owned 50% and Elwood was therefore considered an equity method investment.
(2) Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018.
Dominion's equity earnings on these investments totaled $14 million, $25 million and $35 million in 2013, 2012 and 2011, respectively. Dominion received distributions from these investments of $33 million, $58 million and $55 million in 2013, 2012, and 2011, respectively. As of December 31, 2013 and 2012, the carrying amount of Dominion's investments exceeded Dominion's share of underlying equity in net assets by approximately $36 million and $30 million, respectively. $28 million of the differences relate to Dominion's investments in wind projects and primarily reflect its capitalized interest during construction and the excess of its cash contributions over the book value of development assets contributed by Dominion's partners for these projects, which are being amortized over the useful lives of the underlying assets. The remaining $8 million of differences reflect equity method goodwill and are not being amortized.
BLUE RACER
In December 2012, Dominion formed a joint venture with Caiman to provide midstream services to natural gas producers operating in the Utica Shale region in Ohio and portions of Pennsylvania. The joint venture, Blue Racer, is an equal partnership between Dominion and Caiman, with Dominion contributing midstream assets and Caiman contributing private equity capital.  In return for its December 2012 contribution of assets to the joint venture, Dominion received a 50% interest in Blue Racer and received $115 million in cash proceeds, resulting in a gain of $72 million ($43 million after-tax), net of transaction fees of $9 million, which is recorded in other operations and maintenance expense in Dominion's Consolidated Statement of Income.
In March 2013, Dominion sold Line TL-404 to Blue Racer and received approximately $47 million in cash proceeds resulting in an approximately $25 million ($14 million after-tax) gain. Phase 1 of the Natrium natural gas processing and fractionation facility was completed in the second quarter of 2013 and was contributed to Blue Racer in the third quarter of 2013, resulting in an increased equity method investment in Blue Racer of $473 million. Also in the third quarter of 2013, Dominion sold Line TPL-2A and Line TL-388 to Blue Racer and received approximately $83 million in cash proceeds resulting in an approximately $75 million ($42 million after-tax) gain. In the fourth quarter of 2013, Dominion sold the Western System to Blue Racer for $30 million in cash proceeds resulting in an approximately $4 million ($2 million after-tax) gain. Dominion NGL Pipelines, LLC was contributed in January 2014 to Blue Racer prior to commencement of service, resulting in an increased equity method investment of $155 million.
The joint venture is leveraging Dominion's existing presence in the Utica region with significant additional new capacity designed to meet producer needs as the Utica Shale acreage is developed. Midstream services offered include gathering, processing, fractionation, and NGL transportation and marketing. In addition to the assets already sold or contributed, Dominion expects to sell additional East Ohio gathering assets to Blue Racer.
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			Total			Total				Fair
	Cost			Unrealized			Unrealized				Value
				Gains (1)			Losses (1)
(millions)
2013
Marketable equity securities:
U.S.:
Large Cap	$	506		$	514		$	—			$	1,020
Other	25			11			—				36
Marketable debt securities:
Corporate debt instruments	185			8			(2		)		191
U.S. Treasury securities and agency debentures	214			1			(3		)		212
State and municipal	163			4			(4		)		163
Cost method investments	106			—			—				106
Cash equivalents and other(2)	37			—			—				37
Total	$	1,236		$	538		$	(9	)	(3)	$	1,765
2012
Marketable equity securities:
U.S.:
Large Cap	$	481		$	298		$	—			$	779
Other	20			7			—				27
Marketable debt securities:
Corporate debt instruments	179			17			—				196
U.S. Treasury securities and agency debentures	231			4			(1		)		234
State and municipal	106			11			—				117
Other	1			—			—				1
Cost method investments	117			—			—				117
Cash equivalents and other(2)	44			—			—				44
Total	$	1,179		$	337		$	(1	)	(3)	$	1,515
-1	Included in AOCI and the decommissioning trust regulatory liability as discussed in Note 2.
-2	Includes pending sales of securities of $6 million at December 31, 2013 and 2012.
-3	The fair value of securities in an unrealized loss position was $299 million and $104 million at December 31, 2013 and 2012, respectively.
The fair value of Virginia Power's debt securities at December 31, 2013, by contractual maturity is as follows:
	Amount
(millions)
Due in one year or less	$	31
Due after one year through five years	163
Due after five years through ten years	196
Due after ten years	176
Total	$	566
Presented below is selected information regarding Virginia Power's marketable equity and debt securities.
Year Ended December 31,	2013			2012			2011
(millions)
Proceeds from sales	$	572		$	626		$	1,030
Realized gains(1)	52			42			34
Realized losses(1)	14			11			34
-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability as discussed in Note 2.
Virginia Power recorded other-than-temporary impairment losses on investments as follows:
Year Ended December 31,	2013			2012			2011
(millions)
Total other-than-temporary impairment losses(1)	$	15		$	11		$	29
Losses recorded to decommissioning trust regulatory liability	(13		)	(10		)	(24		)
Losses recorded in other comprehensive income (before taxes)	(1		)	—			(1		)
Net impairment losses recognized in earnings	$	1		$	1		$	4
-1	Amounts include other-than-temporary impairment losses for debt securities of $9 million, $2 million and $4 million at December 31, 2013, 2012 and 2011, respectively.
OTHER INVESTMENTS
Dominion and Virginia Power hold restricted cash and cash equivalent balances that primarily consist of money market fund investments held in trust for the purpose of funding certain qualifying construction projects. At December 31, 2013 and 2012, Dominion had $11 million and $37 million, respectively, and Virginia Power had $8 million and $10 million, respectively, of restricted cash and cash equivalents. These balances are presented in Other Current Assets and Other Investments in the Consolidated Balance Sheets.

Property_Plant_and_Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment, Net [Abstract]	'
Property, Plant and Equipment	'
	PROPERTY, PLANT AND EQUIPMENT
	Major classes of property, plant and equipment and their respective balances for the Companies are as follows:
	At December 31,	2013			2012
	(millions)
	Dominion
	Utility:
	Generation	$	14,018		$	13,707
	Transmission	8,686			7,799
	Distribution	11,714			11,071
	Storage	2,190			2,137
	Nuclear fuel	1,375			1,277
	Gas gathering and processing	787			803
	General and other	812			803
	Other-including plant under construction	3,261			2,232
	Total utility	42,843			39,829
	Nonutility:
	Merchant generation-nuclear	1,153			1,163
	Merchant generation-other(1)	1,328			1,289
	Nuclear fuel	770			775
	Other-including plant under construction	875			1,265
	Total nonutility	4,126			4,492
	Total property, plant and equipment	$	46,969		$	44,321
	Virginia Power
	Utility:
	Generation	$	14,018		$	13,707
	Transmission	4,959			4,261
	Distribution	9,103			8,701
	Nuclear fuel	1,375			1,277
	General and other	668			659
	Other-including plant under construction	2,719			2,017
	Total utility	32,842			30,622
	Nonutility-other	6			9
	Total property, plant and equipment	$	32,848		$	30,631
	-1	2012 amount includes $957 million due to consolidation of a VIE. See Note 15 for further information.
	Jointly-Owned Power Stations
	Dominion's and Virginia Power's proportionate share of jointly-owned power stations at December 31, 2013 is as follows:
		Bath			North			Clover			Millstone
		County			Anna Units 1 and 2(1)			Power			Unit 3(2)
		Pumped						Station(1)
		Storage
		Station(1)
	(millions, except percentages)
	Ownership interest	60		%	88.4		%	50		%	93.5		%
	Plant in service	$	1,038		$	2,486		$	568		$	1,007
	Accumulated depreciation	(536		)	(1,109		)	(199		)	(262		)
	Nuclear fuel	—			597			—			388
	Accumulated amortization of nuclear fuel	—			(434		)	—			(283		)
	Plant under construction	23			76			6			69
	-1	Units jointly owned by Virginia Power.
	-2	Unit jointly owned by Dominion.
	The co-owners are obligated to pay their share of all future construction expenditures and operating costs of the jointly-owned facilities in the same proportion as their respective ownership interest. Dominion and Virginia Power report their share of operating costs in the appropriate operating expense (electric fuel and other energy-related purchases, other operations and maintenance, depreciation, depletion and amortization and other taxes, etc.) in the Consolidated Statements of Income.
	Assignment of Marcellus Acreage
	In December 2013, DTI closed on agreements with two natural gas producers to convey approximately 100,000 acres of Marcellus Shale development rights underneath several of its natural gas storage fields. The agreements provide for payments to DTI, subject to customary adjustments, of approximately $200 million over a period of nine years, and an overriding royalty interest in gas produced from the acreage. In 2013, Dominion received approximately $100 million in cash proceeds, resulting in an approximately $20 million ($12 million-after tax) gain and approximately $80 million deferred revenue, which will be recognized over the remaining terms of the agreements.

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill and Intangible Assets	'
	GOODWILL AND INTANGIBLE ASSETS
	Goodwill
	The changes in Dominion's carrying amount and segment allocation of goodwill are presented below:
		Dominion				Dominion				DVP				Corporate		Total
		Generation				Energy								and
														Other(1)
	(millions)
	Balance at December 31, 2011(2)	$	1,503		(3)	$	712			$	926		(3)	$	—	$	3,141
	Asset disposition adjustment	—				(11		)	(5)	—				—		(11		)
	Balance at December 31, 2012(2)	$	1,503			$	701			$	926			$	—	$	3,130
	Asset disposition adjustment	(19		)	(4)	(25		)	(5)	—				—		(44		)
	Balance at December 31, 2013(2)	$	1,484			$	676			$	926			$	—	$	3,086
	-1	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.
	-2	Goodwill amounts do not contain any accumulated impairment losses.
	-3	Recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.
	-4	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
	-5	Related to assets sold or contributed to Blue Racer.
	Other Intangible Assets
	Dominion's and Virginia Power's other intangible assets are subject to amortization over their estimated useful lives. Dominion's amortization expense for intangible assets was $72 million, $82 million and $78 million for 2013, 2012 and 2011, respectively. In 2013, Dominion acquired $81 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of approximately 10 years. Amortization expense for Virginia Power's intangible assets was $22 million for 2013, 2012, and 2011. In 2013, Virginia Power acquired $14 million of intangible assets, primarily representing software, with an estimated weighted-average amortization period of 5 years. The components of intangible assets are as follows:
	At December 31,	2013						2012
		Gross			Accumulated			Gross			Accumulated
		Carrying			Amortization			Carrying			Amortization
		Amount						Amount
	(millions)
	Dominion
	Software, licenses and other	$	867		$	308		$	859		$	327
	Emissions allowances	3			2			5			1
	Total	$	870		$	310		$	864		$	328
	Virginia Power
	Software, licenses and other	$	271		$	78		$	303		$	122
	Total	$	271		$	78		$	303		$	122
	Annual amortization expense for these intangible assets is estimated to be as follows:
		2014			2015			2016			2017			2018
	(millions)
	Dominion	$	69		$	59		$	50		$	40		$	29
	Virginia Power	$	21		$	15		$	12		$	9		$	5

Regulatory_Assets_and_Liabilit

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Regulatory Assets and Liabilities	'
	REGULATORY ASSETS AND LIABILITIES
	Regulatory assets and liabilities include the following:
	At December 31,	2013		2012
	(millions)
	Dominion
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	89	$	55
	Unrecovered gas costs(2)	50		59
	Virginia sales taxes(3)	46		37
	Derivatives(4)	16		—
	Plant retirement(5)	1		25
	Other	15		27
	Regulatory assets-current(6)	217		203
	Unrecognized pension and other postretirement benefit costs(7)	706		1,210
	Deferred rate adjustment clause costs(1)	287		173
	Income taxes recoverable through future rates(8)	155		140
	Derivatives(4)	16		105
	Other postretirement benefit costs(9)	12		21
	Plant retirement(5)	10		11
	Other	42		57
	Regulatory assets-non-current	1,228		1,717
	Total regulatory assets	$	1,445	$	1,920
	Regulatory liabilities:
	PIPP(10)	$	76	$	100
	Deferred cost of fuel used in electric generation(11)	24		7
	Other	28		29
	Regulatory liabilities-current(12)	128		136
	Provision for future cost of removal and AROs(13)	1,028		985
	Decommissioning trust(14)	693		501
	Unrecognized pension and other postretirement benefit costs(7)	174		2
	Deferred cost of fuel used in electric generation(11)	90		13
	Other	16		13
	Regulatory liabilities-non-current	2,001		1,514
	Total regulatory liabilities	$	2,129	$	1,650
	Virginia Power
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	62	$	51
	Virginia sales taxes(3)	46		37
	Derivatives(4)	16		—
	Plant retirement(5)	1		25
	Other	3		6
	Regulatory assets-current	128		119
	Deferred rate adjustment clause costs(1)	227		127
	Income taxes recoverable through future rates(8)	124		110
	Derivatives(4)	16		105
	Plant retirement(5)	10		11
	Other	40		43
	Regulatory assets-non-current	417		396
	Total regulatory assets	$	545	$	515
	Regulatory liabilities:
	Deferred cost of fuel used in electric generation(11)	$	24	$	7
	Other	17		25
	Regulatory liabilities-current	41		32
	Provision for future cost of removal(13)	807		763
	Decommissioning trust(14)	693		501
	Deferred cost of fuel used in electric generation(11)	90		14
	Other	7		7
	Regulatory liabilities-non-current	1,597		1,285
	Total regulatory liabilities	$	1,638	$	1,317
	-1	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information.
	(2) Reflects unrecovered gas costs at Dominion's regulated gas operations, which are recovered through annual filings with the applicable regulatory authority.
	-3	Amounts to be recovered through an annual surcharge to reimburse Virginia Power for incremental sales taxes being incurred due to the repeal of the public service company sales tax exemption in Virginia.
	-4	As discussed under Derivative Instruments in Note 2, 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.
-5	Reflects costs anticipated to be recovered in North Carolina base rates for certain coal units expected to be retired.
(6) Current regulatory assets are presented in other current assets in Dominion's Consolidated Balance Sheets.
-7	Represents unrecognized pension and other postretirement benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's rate-regulated subsidiaries.
-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	Primarily reflects costs recognized in excess of amounts included in regulated rates charged by Dominion's regulated gas operations before rates were updated to reflect a change in accounting method for other postretirement benefit costs.
-10	Under PIPP, eligible customers can receive energy assistance based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information regarding PIPP.
-11	Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Virginia Power's generation operations. For 2013, amount includes approximately $5 million related to DOE claims. See Note 13 for more information.
(12) Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
-13	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.
-14	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power's utility nuclear generation stations, in excess of the related ARO.
At December 31, 2013, approximately $129 million of Dominion's and $63 million of Virginia Power's regulatory assets represented past expenditures on which they do not currently earn a return. The majority of these expenditures are expected to be recovered within the next two years.

Regulatory_Matters

Regulatory Matters	12 Months Ended
	Dec. 31, 2013
Regulatory Matters [Abstract]	'
Regulatory Matters	'
	REGULATORY MATTERS
	Regulatory Matters Involving Potential Loss Contingencies
	As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the 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 and involves elements of judgment and significant uncertainties. Any estimated range of possible loss does 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 Dominion's or Virginia Power's 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 and ISO-NE wholesale markets 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 July 2008, Virginia Power filed an application with FERC requesting a revision to its revenue requirement to reflect an additional ROE incentive adder for eleven electric transmission enhancement projects. Under the proposal, the cost of transmission service would increase to include an ROE incentive adder for each of the eleven projects, beginning the date each project enters commercial operation (but not before January 1, 2009). Virginia Power proposed an incentive of 1.5% for four of the projects (including the Meadow Brook-to-Loudoun and Carson-to-Suffolk lines, which were completed in 2011) and an incentive of 1.25% for the other seven projects. In August 2008, FERC approved the proposal, effective September 1, 2008, the incentives were included in the PJM Tariff, and billing for the incentives was made accordingly. In 2012, PJM canceled one of the eleven projects with an estimated cost of $7 million. The total cost for the other ten projects included in Virginia Power's formula rate for 2014 is $857 million and the remaining projects were completed by 2012.  Numerous parties sought rehearing of the FERC order in August 2008. In May 2012, FERC issued an order denying the rehearing requests.  In July 2012, the North Carolina Commission filed an appeal of the FERC orders with the U.S. Court of Appeals for the Fourth Circuit. In January 2014, the court rejected the appeal and affirmed FERC's decision granting the incentives.
	In March 2010, ODEC and NCEMC filed a complaint with FERC against Virginia Power claiming that approximately $223 million in transmission costs related to specific projects were unjust, unreasonable and unduly discriminatory or preferential and should be excluded from Virginia Power's transmission formula rate. ODEC and NCEMC requested that FERC establish procedures to determine the amount of costs for each applicable project that should be excluded from Virginia Power's rates. In October 2010, FERC issued an order dismissing the complaint in part and established hearings and settlement procedures on the remaining part of the complaint.  In February 2012, Virginia Power submitted to FERC a settlement agreement to resolve all issues set for hearing.  All transmission customer parties to the proceeding joined the settlement. The Virginia Commission, North Carolina Commission and Public Staff of the North Carolina Commission, while not parties to the settlement, have agreed to not oppose the settlement. The settlement was accepted by FERC in May 2012 and provides for payment by Virginia Power to the transmission customer parties collectively of $250,000 per year for ten years and resolves all matters other than allocation of the incremental cost of certain underground transmission facilities, which has been briefed pursuant to FERC's May 2012 order and awaits FERC action. While Virginia Power cannot predict the outcome of the briefing, it is not expected to have a material effect on results of operations.
	Other Regulatory Matters
	Electric Regulation in Virginia
	The Regulation Act enacted in 2007 instituted a cost-of-service rate model, ending Virginia's planned transition to retail competition for electric supply service to most classes of customers.
	The Regulation Act authorizes stand-alone rate adjustment clauses for recovery of costs for new generation projects, FERC-approved transmission costs, environmental compliance, conservation and energy efficiency programs and renewable energy programs, and also constitutes statutory provisions directing Virginia Power to file annual fuel cost recovery cases with the Virginia Commission. As amended, it provides for enhanced returns on capital expenditures on specific newly proposed generation projects.
	If the Virginia Commission's future rate decisions, including actions relating to Virginia Power's rate adjustment clause filings, differ materially from Virginia Power's expectations, it may adversely affect its results of operations, financial condition and cash flows.
	2013 Biennial Review
	Pursuant to the Regulation Act, in March 2013, Virginia Power submitted its base rate filings and accompanying schedules in support of the Virginia Commission's 2013 biennial review of Virgina Power's rates, terms and conditions, as well as of Virginia Power's earnings for 2011 and 2012 test periods. The Virginia Power earnings test analysis reviewed by the Virginia Commission reflected an ROE of 10.30% on its generation and distribution services earnings for the combined test periods.
	In November 2013, the Virginia Commission issued its 2013 Biennial Review Order. After deciding eleven contested earnings test adjustments, the Virginia Commission ruled that Virginia Power earned on average an ROE of approximately 10.25% on its generation and distribution services for the combined 2011 and 2012 test periods. Because this ROE was more than 50 basis points below Virginia Power’s authorized ROE of 10.9%, the Virginia Commission authorized the deferred recovery, for earnings test purposes, of $23 million in costs related to asset impairments with early retirement decisions, severe weather events, and natural disasters to be amortized over the 2013 calendar year. The Virginia Commission did not order a base rate increase because Virginia Power had previously waived its right to any such increase, and because it determined that Virginia Power had a revenue sufficiency of approximately $280 million when projecting the annual revenues generated by base rates to the revenues required to cover costs of service and earn a fair return. As part of its revenue sufficiency determination, the Virginia Commission also made findings on eleven rate case adjustments, in addition to changes to the cost of capital and capital structure, which resulted in changes to Virginia Power’s rate year revenues and expenses, and Virginia Power’s rate base for generation and distribution, for the rate year beginning January 1, 2014. Virginia Power incurred a $55 million ($37 million after-tax) charge in connection with the 2013 Biennial Review Order.
	In its 2013 Biennial Review Order, the Virginia Commission also set the ROE that will be used in Virginia Power’s 2015 biennial review earnings test analysis for earnings on generation and distribution services for the combined 2013 and 2014 test periods, and that will be applied to Riders R, S, W, B, BW, C1A, and C2A. Pursuant to the Regulation Act, Virginia Power’s authorized ROE can be no lower than the average of the returns reported for the three previous years by not less than a majority of comparable utilities in the Southeastern U.S., subject to certain limitations as described in the Regulation Act. Following this statutory peer group analysis, the Virginia Commission determined that the peer group floor ROE for Virginia Power was 9.89%. It further held, declining to increase or decrease Virginia Power’s combined rate of return based on performance, that Virginia Power’s ROE for earnings test purposes in its 2015 biennial review and for rate adjustment clause purposes is 10.0%, consistent with its determination that Virginia Power’s market cost of equity is 10.0%.
	Virginia Fuel Expenses
	In May 2013, Virginia Power submitted its annual fuel factor filing to the Virginia Commission, proposing an increase of approximately $162 million in fuel revenue for the rate year beginning July 1, 2013. In June 2013, the Virginia Commission issued an order approving the rate.
	In November 2013, the Virginia Commission approved Virginia Power’s voluntary request to reduce Virginia Power’s currently-approved fuel factor rate from 2.942 ¢/kWh to 2.572 ¢/kWh effective for usage on and after December 1, 2013, due to an expected over-recovery of fuel costs. This request is expected to reduce Virginia Power’s anticipated fuel recoveries through June 30, 2014 by more than $140 million. At December 31, 2013, Virginia Power's Consolidated Balance Sheets reflected $24 million of other current liabilities and $85 million of noncurrent regulatory liabilities related to the over-recovered fuel costs.
	Rate Adjustment Clauses
	Below is a discussion of significant riders associated with various Virginia Power projects:
	•	In 2012, the Virginia Commission approved the conversion of the Altavista, Hopewell, and Southampton power stations to biomass, and in conjunction approved Rider B. Virginia Power proposed an approximately $16 million revenue requirement for the rate year beginning April 1, 2014. This case is pending.
	•	In 2013, the Virginia Commission approved Virginia Power's request to construct and operate Brunswick County, and in conjunction approved the associated transmission facilities and Rider BW. Virginia Power proposed an approximately $101 million revenue requirement for the rate year beginning September 1, 2014. This case is pending.
	•	The Virginia Commission previously approved Rider S in conjunction with the Virginia City Hybrid Energy Center. Virginia Power proposed an approximately $248 million revenue requirement for the rate year beginning April 1, 2014. This case is pending.
	•	The Virginia Commission previously approved Rider W in conjunction with Warren County. Virginia Power proposed an approximately $101 million total revenue requirement for the rate year beginning April 1, 2014. This case is pending.
	•	The Virginia Commission approved Riders C1A and C2A in connection with various DSM programs. The requested revenue requirements are approximately $1 million for Rider C1A and approximately $35 million for Rider C2A. This case is pending.
	•	In May 2013, Virginia Power filed for an adjustment to its current Rider T1 with the Virginia Commission for the rate year beginning September 1, 2013, which reflects a total revenue requirement of approximately $404 million.  In July 2013, the Virginia Commission issued an order approving the rate.
	Bremo Power Station
	In September 2013, the Virginia Commission issued its final order approving an amended and reissued CPCN that would allow Virginia Power to convert Bremo Units 3 and 4 from using coal to natural gas as their fuel source. The proposed conversion will preserve 227 MW (net) of existing capacity and is expected to cost approximately $53 million, excluding financing costs.
	North Anna
	Virginia Power is considering the construction of a third nuclear unit at a site located at North Anna. In April 2013, Virginia Power decided to replace the reactor design previously selected for a potential unit with ESBWR technology.
	If Virginia Power decides to build a new unit, it must first receive a COL from the NRC, the approval of the Virginia Commission and certain environmental permits and other approvals. Virginia Power filed the first of its two-part amendment to the COL application with the NRC in July 2013 to reflect the ESBWR technology, and filed the second part of the amendment in December 2013. A COL is expected in 2015. Virginia Power has not yet committed to building a new nuclear unit at North Anna.
	In May 2013, BREDL filed a motion with the NRC ASLB to reopen the COL adjudicatory proceeding relating to North Anna based on new information, citing the change in reactor technology. The motion did not propose any new contentions but asked that either (i) the proceeding be restarted from the beginning by submittal of a new application and renoticing in the Federal Register, or (ii) the proceeding be reopened pending submittal of new contentions, which BREDL would be given an extended amount of time to file.
	In July 2013, the ASLB issued an order holding BREDL’s motion in abeyance. The ASLB noted that because BREDL proposed no contentions, it could not determine whether any portion of the motion falls within the ASLB’s jurisdiction, which is currently limited to ruling on a September 2011 petition filed by BREDL to reopen the COL proceeding related to seismic issues. In January 2014, Virginia Power informed the ASLB and parties that the Company’s assessment of seismic issues was complete. Under a previous ruling of the ASLB, BREDL will have a period of 60 days from the time Virginia Power informs the NRC and parties that its seismic assessment is complete to submit a motion to reopen the proceeding on this topic.
	Legislation has been proposed that would limit the portion of costs incurred by an investor-owned electric utility between July 1, 2007 and December 31, 2013, in developing a nuclear power facility or an offshore wind project that are recoverable from Virginia jurisdictional and non-jurisdictional customers through a future rate adjustment clause to a maximum of 30% of such amount. Virginia Power has deferred or capitalized costs totaling $570 million as of December 31, 2013 related to the development of a third nuclear unit site located at North Anna. If this proposed legislation is enacted, 70% of the costs previously deferred or capitalized would be recovered from Virginia jurisdictional and non-jurisdictional ratepayers as part of the 2013 and 2014 base rates. Upon enactment, Virginia Power would recognize 70% of the costs previously deferred or capitalized against net income in 2014. The remaining deferred or capitalized costs, as well as costs incurred after December 31, 2013, would continue to be eligible for inclusion in a future rate adjustment clause.
	Electric Transmission Projects
	In January 2013, a notice of appeal was filed with the Supreme Court of Virginia by a private party regarding the Virginia Commission's December 2012 order granting a CPCN and authorizing construction of the Waxpool-Brambleton-BECO line. In October 2013, the Supreme Court of Virginia issued an opinion affirming the Virginia Commission’s decision.
	In October 2013, Virginia Power applied for a CPCN to rebuild within existing rights-of-way its existing 500 kV Loudoun-Pleasant View transmission line in Loudoun County. As stated in the application, the project is needed to address NERC Reliability Standards violations projected to occur in 2016 and to replace aging transmission facilities. This case is pending.
	In November 2013, the Virginia Commission issued an order granting Virginia Power a CPCN to construct approximately 7 miles of new overhead 500 kV transmission line from the existing Surry Switching Station in Surry County to a new Skiffes Creek Switching Station in James City County, and approximately 20 miles of new 230 kV transmission line in James City County, York County, and the City of Newport News from the proposed new Skiffes Creek Switching Station to Virginia Power’s existing Whealton Substation in the City of Hampton. In December 2013, Virginia Power filed a motion for reconsideration to the Virginia Commission and a notice to appeal the Virginia Commission's order to the Supreme Court of Virginia. The Virginia Commission granted reconsideration and ordered a hearing, which was held in January 2014. The matter is pending at the Virginia Commission. The projected in-service date for this transmission project has been delayed until December 2015 at the earliest.
	Ohio Regulation
	PIR Program
	In 2008, East Ohio began PIR, aimed at replacing approximately 20% of its pipeline system, or approximately 4,100 miles, over a 25-year period. In February 2013, East Ohio filed an application with the Ohio Commission to adjust the cost recovery charge for costs associated with PIR investments for the calendar year 2012 and cumulatively. The application includes total gross plant investment for 2012 of $148 million, cumulative gross plant investment of $511 million, and a revenue requirement of $67 million. The Ohio Commission issued an order approving the rates in April 2013. In May 2013, the approved PIR cost recovery rates became effective.
	In November 2013, East Ohio filed a notice to adjust the PIR cost recovery for 2013 costs. The filing reflects projected gross plant investment for 2013 of $170 million, cumulative gross plant investment of $681 million and an estimated revenue requirement of approximately $90 million. This case is pending.
	PIPP Plus Program
	Under the Ohio PIPP Plus Program, eligible customers can receive energy assistance based on their ability to pay their bill. The difference between the customer's total bill and the PIPP payment plan amount is deferred and collected under the PIPP rider in accordance with the rules of the Ohio Commission. In July 2013, the Ohio Commission approved East Ohio's annual update of the PIPP Rider, which reflects the refund over the next year of an over-recovery of accumulated arrearages of approximately $91 million as of March 31, 2013, net of projected deferred program costs of approximately $54 million for the period from April 2013 through June 2014.
	FERC Regulation
	DTI Fuel Settlement
	In mid-2013, DTI received concerns about its fuel retainage percentages and apparent over-recovery of fuel costs during certain time periods reflected in its annual fuel reports. In December 2013, DTI submitted for FERC approval a stipulation and agreement addressing, among other things, reductions in its fuel retainage percentages.
	In February 2014, FERC approved the stipulation and agreement. DTI will implement the reduced fuel retainage percentages effective March 1, 2014. DTI will also provide refunds with interest to each settling customer reflecting the value of the actual quantities of fuel retained from that party between January 1, 2014 and the March 1, 2014 implementation date. This agreement is expected to reduce DTI’s revenues by approximately $35 million in 2014.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligations	'
	ASSET RETIREMENT OBLIGATIONS
	AROs represent obligations that result from laws, statutes, contracts and regulations related to the eventual retirement of certain of Dominion's and Virginia Power's long-lived assets. Dominion's and Virginia Power's AROs are primarily associated with the decommissioning of their nuclear generation facilities. In addition, Dominion's AROs include plugging and abandonment of gas and oil wells, interim retirements of natural gas gathering, transmission, distribution and storage pipeline components, and the future abatement of asbestos expected to be disturbed in the Companies' generation facilities.
	The Companies have also identified, but not recognized, AROs related to retirement of Dominion's LNG facility, Dominion's gas storage wells in its underground natural gas storage network, certain Virginia Power electric transmission and distribution assets located on property with easements, rights of way, franchises and lease agreements, Virginia Power's hydroelectric generation facilities and the abatement of certain asbestos not expected to be disturbed in the Companies' generation facilities. The Companies currently do not have sufficient information to estimate a reasonable range of expected retirement dates for any of these assets since the economic lives of these assets can be extended indefinitely through regular repair and maintenance and they currently have no plans to retire any of these assets. As a result, a settlement date is not determinable for these assets and AROs for these assets will not be reflected in the Consolidated Financial Statements until sufficient information becomes available to determine a reasonable estimate of the fair value of the activities to be performed. The Companies continue to monitor operational and strategic developments to identify if sufficient information exists to reasonably estimate a retirement date for these assets. The changes to AROs during 2012 and 2013 were as follows:
		Amount
	(millions)
	Dominion
	AROs at December 31, 2011(1)	$	1,398
	Obligations incurred during the period	24
	Obligations settled during the period	(13		)
	Revisions in estimated cash flows(2)	242
	Accretion	77
	Other	(23		)
	AROs at December 31, 2012(1)	$	1,705
	Obligations incurred during the period	13
	Obligations settled during the period	(68		)
	Revisions in estimated cash flows(3)	(129		)
	Accretion	86
	Other	(29		)
	AROs at December 31, 2013(1)	$	1,578
	Virginia Power
	AROs at December 31, 2011(4)	$	625
	Obligations incurred during the period	18
	Obligations settled during the period	(1		)
	Revisions in estimated cash flows(5)	41
	Accretion	34
	Other	(12		)
	AROs at December 31, 2012	$	705
	Obligations incurred during the period	2
	Obligations settled during the period	(2		)
	Revisions in estimated cash flows(3)	(52		)
	Accretion	38
	Other	(2		)
	AROs at December 31, 2013	$	689
	-1	Includes $15 million, $64 million and $94 million reported in other current liabilities at December 31, 2011, 2012, and 2013, respectively.
	-2	Primarily reflects the accelerated timing of the decommissioning of Kewaunee that began in 2013.
	-3	Primarily reflects lower anticipated nuclear decommissioning costs.
	-4	Includes $1 million reported in other current liabilities.
	-5	Primarily reflects the effect of higher anticipated nuclear decommissioning costs.
	Dominion and Virginia Power have established trusts dedicated to funding the future decommissioning of their nuclear plants. At December 31, 2013 and 2012, the aggregate fair value of Dominion's trusts, consisting primarily of equity and debt securities, totaled $3.9 billion and $3.3 billion, respectively. At December 31, 2013 and 2012, the aggregate fair value of Virginia Power's trusts, consisting primarily of debt and equity securities, totaled $1.8 billion and $1.5 billion, respectively.

Variable_Interest_Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2013
Variable Interest Entities [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.
	Virginia Power has long-term power and capacity contracts with four non-utility generators with an aggregate summer generation capacity of approximately 870 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 2015 to 2021. Virginia Power is not subject to any risk of loss from these potential VIEs other than its remaining purchase commitments which totaled $864 million as of December 31, 2013. Virginia Power paid $217 million, $214 million, and $211 million for electric capacity and $98 million, $83 million, and $125 million for electric energy to these entities for the years ended December 31, 2013, 2012 and 2011, respectively.
	Virginia Power purchased shared services from DRS, an affiliated VIE, of approximately $331 million, $328 million, and $389 million for the years ended December 31, 2013, 2012 and 2011, respectively. Virginia Power determined that it is not the most closely associated entity with DRS and therefore not the primary beneficiary. DRS provides accounting, legal, finance and certain administrative and technical services to all Dominion subsidiaries, including Virginia Power. Virginia Power has no obligation to absorb more than its allocated share of DRS costs.
	Through August 2013, Dominion leased the Fairless generating facility in Pennsylvania from Juniper, the lessor, which began commercial operations in June 2004. Dominion made annual lease payments of approximately $53 million.
	Juniper was formed in 2003 as a limited partnership and was organized for the purpose of acquiring and constructing a number of assets for lease. Such assets were financed with proceeds from the issuance of bank debt, privately placed long-term debt and partnership capital received from Juniper's general and limited partners. Dominion had no voting equity interest in Juniper. Because Juniper had been subject to the business scope exception, Dominion was not required to evaluate whether Juniper was a VIE prior to October 2011.
	Through September 30, 2011, Juniper held various power plant leases, including Fairless. In October 2011, the last lease other than Fairless expired and the related asset was sold by Juniper. With Fairless being its sole remaining asset, Juniper no longer qualified as a business as of October 2011, which required that Dominion determine whether Juniper was a VIE. Dominion concluded Juniper was a VIE because the entity's capitalization was insufficient to support its operations, the power to direct the most significant activities of the entity was not held by the equity holders, and Dominion guaranteed a portion of the residual value of Fairless. The activities that most significantly impacted Juniper's economic performance related to the operation of Fairless. The decisions related to the operations of Fairless were made by Dominion and as such, Dominion was considered the primary beneficiary.
	Accordingly, Dominion consolidated Juniper in October 2011 and recorded, at fair value, approximately $957 million of property, plant and equipment, $896 million of debt and $61 million of noncontrolling interests. The debt was non-recourse to Dominion and was secured by Juniper's assets. The annual lease payments made by Dominion to Juniper for Fairless were eliminated in the Consolidated Statements of Income and were excluded from the lease commitments table in Note 22 to the Consolidated Financial Statements in Dominion’s and Virginia Power’s Annual Report on Form 10-K for the year ended December 31, 2012. Dominion did not provide any financial or other support to Juniper that it was not previously contractually required to provide.
	In August 2013, the lease expired and Dominion purchased Fairless for $923 million from Juniper per the terms of the lease agreement. However, as Dominion had previously consolidated Juniper, the purchase was accounted for as an equity transaction to acquire the noncontrolling interests from Juniper for $923 million, while Dominion retained control of Fairless. The acquisition resulted in the removal of securities due within one year-VIE and noncontrolling interests from Dominion's Consolidated Balance Sheet during 2013.

ShortTerm_Debt_And_Credit_Agre

Short-Term Debt And Credit Agreements	12 Months Ended
	Dec. 31, 2013
Short-term Debt, Other Disclosures [Abstract]	'
Short-Term Debt And Credit Agreements	'
	SHORT-TERM DEBT AND CREDIT AGREEMENTS
	Dominion and Virginia Power 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
	Commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:
		Facility		Outstanding			Outstanding		Facility
		Limit		Commercial			Letters of		Capacity
				Paper			Credit		Available
	(millions)
	At December 31, 2013
	Joint revolving credit facility(1)	$	3,000	$	1,927		$	—	$	1,073
	Joint revolving credit facility(2)	500		—			11		489
	Total	$	3,500	$	1,927	(3)	$	11	$	1,562
	At December 31, 2012
	Joint revolving credit facility(1)	$	3,000	$	2,412		$	—	$	588
	Joint revolving credit facility(2)	500		—			26		474
	Total	$	3,500	$	2,412	(3)	$	26	$	1,062
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit.
	-2	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by Dominion's credit facilities were 0.33% and 0.49% at December 31, 2013 and 2012, respectively.
	VIRGINIA POWER
	Virginia Power's short-term financing is supported by two joint revolving credit facilities with Dominion. These credit facilities are being used for working capital, as support for the combined commercial paper programs of Dominion and Virginia Power and for other general corporate purposes.
	Virginia Power's share of commercial paper and letters of credit outstanding, as well as its capacity available under its joint credit facilities with Dominion, were as follows:
		Facility Sub-limit		Outstanding Commercial Paper			Outstanding Letters of Credit		Facility Sub-limit Capacity Available
	(millions)
	At December 31, 2013
	Joint revolving credit facility(1)	$	1,000	$	842		$	—	$	158
	Joint revolving credit facility(2)	250		—			1		249
	Total	$	1,250	$	842	(3)	$	1	$	407
	At December 31, 2012
	Joint revolving credit facility(1)	$	1,000	$	992		$	—	$	8
	Joint revolving credit facility(2)	250		—			2		248
	Total	$	1,250	$	992	(3)	$	2	$	256
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility 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. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.
	-2	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.33% and 0.47% at December 31, 2013 and 2012, respectively.
	In addition to the credit facility commitments mentioned above, Virginia Power also has a $120 million credit facility. Effective September 2013, the maturity date was extended from September 2017 to September 2018. As of December 31, 2013, this facility supports approximately $119 million of certain variable rate tax-exempt financings of Virginia Power.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Long-Term Debt	'
	LONG-TERM DEBT
	At December 31,	2013 Weighted-		2013			2012
		average
		Coupon(1)
	(millions, except percentages)
	Virginia Electric and Power Company:
	Unsecured Senior Notes:
	1.2% to 8.625%, due 2013 to 2018	5.09	%	$	2,138		$	2,306
	2.75% to 8.875%, due 2019 to 2043	5.25	%	4,993			3,408
	Tax-Exempt Financings(2):
	Variable rates, due 2016 to 2041	0.98	%	606			454
	1.5% to 5.6%, due 2022 to 2040	3.16	%	306			508
	Virginia Electric and Power Company total principal			$	8,043		$	6,676
	Securities due within one year	4.1	%	(58		)	(418		)
	Unamortized discount and premium, net			(11		)	(7		)
	Virginia Electric and Power Company total long-term debt			$	7,974		$	6,251
	Dominion Resources, Inc.:
	Unsecured Senior Notes:
	Variable rates, due 2013 and 2014	0.37	%	$	400		$	400
	1.4% to 7.195%, due 2013 to 2018	4.03	%	3,291			3,541
	2.75% to 8.875%, due 2019 to 2042(3)	5.64	%	4,599			4,599
	Unsecured Convertible Senior Notes, 2.125%, due 2023(4)			43			82
	Tax-Exempt Financing, variable rate, due 2041(5)	1.12	%	75			—
	Unsecured Junior Subordinated Notes Payable to Affiliated Trusts, 7.83% and 8.4%, due 2027 and 2031	8.4	%	10			268
	Enhanced Junior Subordinated Notes:
	7.5% and 8.375%, due 2064 and 2066	8.11	%	985			985
	Variable rate, due 2066	2.58	%	380			380
	Remarketable Subordinated Notes, 1.07% and 1.18%, due 2019 and 2021	1.13	%	1,100			—
	Unsecured Debentures and Senior Notes(6):
	5.0% and 6.625%, due 2013 and 2014	5	%	600			622
	6.8% and 6.875%, due 2026 and 2027	6.81	%	89			89
	Dominion Gas Holdings, LLC:
	Unsecured Senior Notes, 1.05% to 4.8%, due 2016 to 2043	3.13	%	1,200			—
	Dominion Energy, Inc.:
	Secured Senior Notes:
	5.03% to 5.78%, due 2013(7)			—			842
	7.33%, due 2020(8)			—			145
	Tax-Exempt Financings:
	2.25% to 5.75%, due 2033 to 2042(9)	2.38	%	27			284
	Variable rate, due 2041(5)			—			75
	Virginia Electric and Power Company total principal (from above)			8,043			6,676
	Dominion Resources, Inc. total principal			$	20,842		$	18,988
	Fair value hedge valuation(10)			55			93
	Securities due within one year(11)	2.95	%	(1,519		)	(2,223		)
	Unamortized discount and premium, net			(48		)	(7		)
	Dominion Resources, Inc. total long-term debt			$	19,330		$	16,851
	-1	Represents weighted-average coupon rates for debt outstanding as of December 31, 2013.
	-2	These financings relate to certain pollution control equipment at Virginia Power's generating facilities. Certain variable rate tax-exempt financings are supported by a $120 million credit facility that terminates in September 2018.
	-3	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 and $600 million of Dominion's 8.875% senior notes due 2019 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015 and January 2014, respectively.
	-4	Convertible into a combination of cash and shares of Dominion's common stock at any time when the closing price of common stock equals 120% of the applicable conversion price or higher for at least 20 out of the last 30 consecutive trading days ending on the last trading day of the previous calendar quarter. At the option of holders on December 15, 2018, these securities are subject to redemption at 100% of the principal amount plus accrued interest. These senior notes have been callable by Dominion since December 15, 2011.
	-5	Debt issued by the MDFA on behalf of Brayton Point. In connection with the sale of Brayton Point, the sole obligor under the bonds was changed from Brayton Point to Dominion in June 2013.
	-6	Represents debt assumed by Dominion from the merger of its former CNG subsidiary.
	-7	Juniper notes issued in 2004 and consolidated in October 2011 due to Dominion becoming the primary beneficiary of this VIE. This amount excludes $18 million of unamortized premium in 2012. The debt was non-recourse to Dominion and was secured by Juniper's assets. Dominion's purchase of Fairless in August 2013 resulted in the removal of the debt from Dominion's Consolidated Balance Sheet. See Note 15 for additional information.
	-8	Represented debt associated with Kincaid. The debt was non-recourse to Dominion and was secured by the facility's assets and revenue. In connection with the sale of Kincaid, the notes were redeemed in May 2013 for approximately $185 million, including a make-whole premium and accrued interest.
	-9	In 2012 included debt issued by the MDFA on behalf of Brayton Point. In connection with the sale of Brayton Point, three series of bonds totaling approximately $257 million were defeased in June 2013. In June 2013, Brayton Point delivered approximately $284 million to fund an irrevocable trust for the purpose of paying maturing principal and interest due through and including the earliest redemption dates of the bonds in 2016 and 2019.
	-10	Represents the valuation of certain fair value hedges associated with Dominion's fixed rate debt.
	-11	Includes $14 million fair value hedge valuation in 2013 and $23 million of net unamortized premium and fair value hedge valuation in 2012.
	Based on stated maturity dates rather than early redemption dates that could be elected by instrument holders, the scheduled principal payments of long-term debt at December 31, 2013, were as follows:
		2014			2015			2016			2017			2018			Thereafter			Total
	(millions, except percentages)
	Virginia Power	$	58		$	211		$	476		$	679		$	850		$	5,769		$	8,043
	Weighted-average Coupon	4.1		%	5.39		%	5.25		%	5.44		%	4.17		%	4.78		%
	Dominion
Unsecured Senior Notes	$	1,465		$	960		$	1,752		$	1,303		$	1,350		$	10,523		$	17,353
Tax-Exempt Financings	40			—			19			75			—			880			1,014
Unsecured Junior Subordinated Notes Payable to Affiliated Trusts	—			—			—			—			—			10			10
Enhanced Junior Subordinated Notes	—			—			—			—			—			1,365			1,365
Remarketable Subordinated Notes	—			—			—			—			—			1,100			1,100
Total	$	1,505		$	960		$	1,771		$	1,378		$	1,350		$	13,878		$	20,842
Weighted-average Coupon	2.95		%	4.45		%	3.51		%	4.55		%	4.99		%	4.9		%
Dominion's and Virginia Power's short-term credit facilities and long-term debt agreements contain customary covenants and default provisions. As of December 31, 2013, there were no events of default under these covenants.
In February 2014, Virginia Power issued $350 million of 3.45% senior notes, and $400 million of 4.45% senior notes, that mature in 2024, and 2044, respectively.
Convertible Securities
At December 31, 2013, Dominion had $43 million of outstanding contingent convertible senior notes that are convertible by holders into a combination of cash and shares of Dominion's common stock under certain circumstances. The conversion feature requires that the principal amount of each note be repaid in cash, while amounts payable in excess of the principal amount will be paid in common stock. The conversion rate is subject to adjustment without limitation upon certain events such as subdivisions, splits, combinations of common stock or the issuance to all common stock holders of certain common stock rights, warrants or options and certain dividend increases. As of December 31, 2013, the conversion rate had been adjusted to 29.8780 shares of common stock per $1,000 principal amount of senior notes, which represents a conversion price of $33.47, primarily due to individual dividend payments above the level paid at issuance. If the outstanding notes as of December 31, 2013 were all converted, it would result in the issuance of approximately 600 thousand additional shares of common stock. In January 2014, Dominion's Board of Directors declared dividends payable March 20, 2014 of 60 cents per share of common stock which will increase the conversion rate to 29.9961 effective as of February 26, 2014.
The senior notes are eligible for conversion during any calendar quarter when the closing price of Dominion's common stock was equal to or higher than 120% of the conversion price for at least 20 out of the last 30 consecutive trading days of the preceding quarter, the notes are called for redemption by Dominion and upon the occurrence of certain other conditions. During 2013, the senior notes were eligible for conversion and approximately $39 million of the notes were converted by holders into $28 million of common stock. The senior notes are eligible for conversion during the first quarter of 2014. Beginning in 2007, the notes have been eligible for contingent interest if the average trading price as defined in the indenture equals or exceeds 120% of the principal amount of the senior notes. Holders have the right to require Dominion to purchase these senior notes for cash at 100% of the principal amount plus accrued interest in December 2018, or if Dominion undergoes certain fundamental changes. The senior notes have been callable by Dominion since December 15, 2011.
Junior Subordinated Notes Payable to Affiliated Trusts
In previous years, Dominion established several subsidiary capital trusts, each as a finance subsidiary of Dominion, which holds 100% of the voting interests. The trusts sold capital securities representing preferred beneficial interests and 97% beneficial ownership in the assets held by the trusts. In exchange for the funds realized from the sale of the capital securities and common securities that represent the remaining 3% beneficial ownership interest in the assets held by the capital trusts, Dominion issued various junior subordinated notes. The junior subordinated notes constitute 100% of each capital trust's assets. Each trust must redeem its capital securities when their respective junior subordinated notes are repaid at maturity or if redeemed prior to maturity.
In January 2013, Dominion repaid its $258 million 7.83% unsecured junior subordinated debentures and redeemed all 250 thousand units of the $250 million 7.83% Dominion Resources Capital Trust I capital securities due December 1, 2027. The securities were redeemed at a price of $1,019.58 per capital security plus accrued and unpaid distributions.
The following table provides summary information about the capital securities and junior subordinated notes outstanding as of December 31, 2013:
Date Established	Capital Trust	Units		Rate		Capital Securities Amount			Common Securities Amount
		(thousands)				(millions)
Jan-01	Dominion Resources Capital Trust III(1)	10		8.4	%	$	10		$	0.3
-1	$10 million-Dominion Resources, Inc. 8.4% Debentures due 1/15/2031 were held as assets by the capital trust.
Interest charges related to Dominion's junior subordinated notes payable to affiliated trusts were $1 million for the year ended December 31, 2013 and $21 million for the years ended December 31, 2012 and 2011.
Enhanced Junior Subordinated Notes
In June 2006 and September 2006, Dominion issued $300 million of June 2006 hybrids and $500 million of September 2006 hybrids, respectively. The June 2006 hybrids will bear interest at 7.5% per year until June 30, 2016. Thereafter, they will bear interest at the three-month LIBOR plus 2.825%, reset quarterly. Beginning September 30, 2011, the September 2006 hybrids bear interest at the three-month LIBOR plus 2.3%, reset quarterly. Previously, interest was fixed at 6.3% per year.
In June 2009, Dominion issued $685 million of 8.375% June 2009 hybrids. The June 2009 hybrids are listed on the NYSE under the symbol DRU.
Dominion may defer interest payments on the hybrids on one or more occasions for up to 10 consecutive years. If the interest payments on the hybrids are deferred, Dominion may not make distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments during the deferral period. Also, during the deferral period, Dominion may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the hybrids.
Dominion executed RCCs in connection with its issuance of all of the hybrids described above. Under the terms of the RCCs, Dominion covenants to and for the benefit of designated covered debtholders, as may be designated from time to time, that Dominion shall not redeem, repurchase, or defease all or any part of the hybrids, and shall not cause its majority owned subsidiaries to purchase all or any part of the hybrids, on or before their applicable RCC termination date, unless, subject to certain limitations, during the 180 days prior to such activity, Dominion has received a specified amount of proceeds as set forth in the RCCs from the sale of qualifying securities that have equity-like characteristics that are the same as, or more equity-like than the applicable characteristics of the hybrids at that time, as more fully described in the RCCs. In September 2011, Dominion amended the RCCs of the June 2006 hybrids and September 2006 hybrids to expand the measurement period for consideration of proceeds from the sale of common stock issuances from 180 days to 365 days. The proceeds Dominion receives from the replacement offering, adjusted by a predetermined factor, must equal or exceed the redemption or repurchase price.
In December 2011, Dominion purchased and canceled approximately $16 million of the September 2006 hybrids. In February 2012, Dominion launched a tender offer to purchase up to $150 million of additional September 2006 hybrids. In the first quarter of 2012, Dominion purchased and canceled approximately $86 million of the September 2006 hybrids primarily as a result of this tender offer, which expired in March 2012. In the second quarter of 2012, Dominion purchased and canceled approximately $2 million of the September 2006 hybrids. All purchases were conducted in compliance with the RCC.
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.
Remarketable Subordinated Notes
In June 2013, Dominion issued $550 million of 2013 Series A 6.125% Equity Units and $550 million of 2013 Series B 6% Equity Units, initially in the form of Corporate Units. The Corporate Units are listed on the NYSE under the symbols DCUA and DCUB, respectively.
Each Corporate Unit consists of a stock purchase contract and 1/20 interest in a RSN issued by Dominion. The stock purchase contracts obligate the holders to purchase shares of Dominion common stock at a future settlement date prior to the relevant RSN maturity date. The purchase price to be paid under the stock purchase contracts is $50 per Corporate Unit and the number of shares to be purchased will be determined under a formula based upon the average closing price of Dominion common stock near the settlement date. The RSNs are pledged as collateral to secure the purchase of common stock under the related stock purchase contracts.
Dominion makes quarterly interest payments on the RSNs and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. Dominion may defer payments on the stock purchase contracts and the RSNs for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, Dominion may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Also, during the deferral period, Dominion may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs.
Dominion has recorded the present value of the stock purchase contract payments as a liability offset by a charge to additional paid-in capital in equity. Interest payments on the RSNs are recorded as interest expense and stock purchase contract payments are charged against the liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense. In calculating diluted EPS, Dominion applies the treasury stock method to the Equity Units. These securities did not have an effect on diluted EPS for the year ended 2013.
Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Dominion will issue between 8.4 million and 9.9 million shares of its common stock in both April 2016 and July 2016. A total of 22.5 million shares of Dominion's common stock has been reserved for issuance in connection with the stock purchase contracts.
Selected information about Dominion's Equity Units is presented below:
Issuance Date	Units Issued	Total Net Proceeds			Total Long-term Debt			RSN Annual Interest Rate		Stock Purchase Contract Annual Rate		Stock Purchase Contract Liability(1)			Stock Purchase Settlement Date	RSN Maturity Date
(millions, except interest rates)
6/7/13	11	$	533.5		$	550		1.07	%	5.055	%	$	76.7		4/1/16	4/1/21
6/7/13	11	$	553.5		$	550		1.18	%	4.82	%	$	79.3		7/1/16	7/1/19
-1	Payments of $17 million were made in 2013. The stock purchase contract liability was $139 million at December 31, 2013.
Regulated Natural Gas Financing Plans
In September 2013, Dominion announced the formation of Dominion Gas, a first tier wholly-owned subsidiary holding company for the majority of Dominion’s regulated natural gas businesses. Specifically, Dominion transferred direct ownership of East Ohio, DTI and Dominion Iroquois, the latter of which holds a 24.72% general partnership interest in Iroquois, to Dominion Gas on September 30, 2013. Dominion intends to seek approval from the West Virginia Commission in 2014 for the transfer of direct ownership of Hope to Dominion Gas. Dominion Gas issued $1.2 billion principal amount of unsecured senior notes in a private placement in October 2013 and will be the primary financing entity for Dominion’s regulated natural gas businesses. Dominion Gas expects to become an SEC registrant in 2014. Dominion Gas used the proceeds from this offering to acquire intercompany long-term notes from Dominion and to repay a portion of its intercompany revolving credit agreement balances with Dominion.

Preferred_Stock

Preferred Stock	12 Months Ended
	Dec. 31, 2013
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]	'
Preferred Stock	'
	PREFERRED STOCK
	Dominion is authorized to issue up to 20 million shares of preferred stock; however, none were issued and outstanding at December 31, 2013 or 2012.
	Virginia Power is authorized to issue up to 10 million shares of preferred stock, $100 liquidation preference, and had 2.59 million preferred shares issued and outstanding at December 31, 2013 and 2012. Upon involuntary liquidation, dissolution or winding-up of Virginia Power, each share would be entitled to receive $100 plus accrued cumulative dividends.
	Holders of Virginia Power's outstanding preferred stock are not entitled to voting rights except under certain provisions of the amended and restated articles of incorporation and related provisions of Virginia law restricting corporate action, upon default in dividends or in special statutory proceedings and as required by Virginia law (such as mergers, consolidations, sales of assets, dissolution and changes in voting rights or priorities of preferred stock).
	Presented below are the series of Virginia Power preferred stock that were outstanding as of December 31, 2013:
	Dividend	Issued and Outstanding Shares	Entitled Per  Share Upon Liquidation
		(thousands)
	$5.00	107	$	112.5
	4.04	13	102.27
	4.2	15	102.5
	4.12	32	103.73
	4.8	73	101
	7.05	500	100
	6.98	600	100
	Flex Money Market Preferred 12/02, Series A	1,250	100		(1)
	Total	2,590
	-1	Effective March 20, 2011 the rate was reset to 6.12% until March 20, 2014 after which the rate was due to be reset through an auction process. However, in February 2014, Virginia Power provided irrevocable notice to redeem the stock on March 20, 2014 at a price of $100 per share plus accumulated and unpaid dividends.

Shareholders_Equity

Shareholders' Equity	12 Months Ended
	Dec. 31, 2013
Stockholders' Equity Note [Abstract]	'
Shareholders' Equity	'
	SHAREHOLDERS' EQUITY
	Issuance of Common Stock
	DOMINION
	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 January 2012, Dominion began issuing new common shares for these direct stock purchase plans.  In January 2014, Dominion began purchasing its common stock on the open market for these plans.
	During 2013, Dominion issued approximately 5.4 million shares of common stock through various programs.  Dominion received cash proceeds of $278 million from the issuance of 4.7 million of such shares through Dominion Direct and employee savings plans.
	In January 2012, Dominion filed a new SEC shelf registration for the sale of debt and equity securities including the ability to sell common stock through an at the market program.  Dominion entered into four separate Sales Agency Agreements to effect sales under the program.  However, with the exception of issuing approximately $317 million in equity through employee savings plans, direct stock purchase and dividend reinvestment plans, converted securities and other employee and director benefit plans, Dominion did not issue common stock in 2013.
	VIRGINIA POWER
	In 2013, 2012 and 2011, Virginia Power did not issue any shares of its common stock to Dominion.
	Shares Reserved for Issuance
	At December 31, 2013, Dominion had approximately 48 million shares reserved and available for issuance for Dominion Direct®, employee stock awards, employee savings plans, director stock compensation plans, contingent convertible senior notes and issuance in connection with stock purchase contracts. See Note 17 for more information.
	Repurchase of Common Stock
	Dominion did not repurchase any shares in 2013 or 2012 and does not plan to repurchase shares during 2014, except for shares tendered by employees to satisfy tax withholding obligations on vested restricted stock and purchases of common stock on the open market in 2014 for direct stock purchase plans, which do not count against its stock repurchase authorization.
	Accumulated Other Comprehensive Income (Loss)
	Presented in the table below is a summary of AOCI by component:
	At December 31,	2013			2012
	(millions)
	Dominion
	Net deferred losses on derivatives-hedging activities, net of tax of $196 and $87	$	(288	)	$	(122	)
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(307) and $(206)	474			326
	Net unrecognized pension and other postretirement benefit costs, net of tax of $365 and $745	(510		)	(1,081		)
	Total AOCI	$	(324	)	$	(877	)
	Virginia Power
	Net deferred losses on derivatives-hedging activities, net of tax of $-- and $3	$	—		$	(6	)
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(30) and $(19)	48			31
	Total AOCI	$	48		$	25
	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			Total
	(millions)
	Year Ended December 31, 2013
	Beginning balance	$	(122	)	$	326		$	(1,081	)	$	(877	)
	Other comprehensive income before reclassifications: gains (losses)	(243		)	203			516			476
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	77			(55		)	55			77
	Net current period other comprehensive income (loss)	(166		)	148			571			553
	Ending balance	$	(288	)	$	474		$	(510	)	$	(324	)
	(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)
	Year Ended December 31, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	58		Operating revenue
		47			Purchased gas
		10			Electric fuel and other energy-related purchases
	Interest rate contracts	15			Interest and related charges
	Total	130
	Tax	(53		)	Income tax expense
	Total, net of tax	$	77
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(98	)	Other income
	Impairment	8			Other income
	Total	(90		)
	Tax	35			Income tax expense
	Total, net of tax	$	(55	)
	Unrecognized pension and other postretirement benefit costs:
	Prior-service costs (credits)	$	(8	)	Other operations and maintenance
	Actuarial losses	102			Other operations and maintenance
	Total	94
	Tax	(39		)	Income tax expense
	Total, net of tax	$	55
	The following table presents Virginia Power’s changes in AOCI by component, net of tax:
		Deferred gains and losses on derivatives-hedging activities			Unrealized gains and losses on nuclear decommissioning trust funds			Total
	(millions)
	Year Ended December 31, 2013
Beginning balance	$	(6	)	$	31		$	25
Other comprehensive income before reclassifications: gains (losses)	6			20			26
Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	—			(3		)	(3		)
Net current period other comprehensive income (loss)	6			17			23
Ending balance	$	—		$	48		$	48
(1) See table below for details about these reclassifications.
The following table presents Virginia Power’s reclassifications out of AOCI by component:
Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
(millions)
Year Ended December 31, 2013
Unrealized (gains) and losses on investment securities:
Realized (gain) loss on sale of securities	$	(6	)	Other income
Impairment	1			Other income
Total	(5		)
Tax	2			Income tax expense
Total, net of tax	$	(3	)
Stock-Based Awards
The 2005 Incentive Compensation Plan permits stock-based awards that include restricted stock, performance grants, goal-based stock, stock options, and stock appreciation rights. The Non-Employee Directors Compensation Plan permits grants of restricted stock and stock options. Under provisions of both plans, employees and non-employee directors may be granted options to purchase common stock at a price not less than its fair market value at the date of grant with a maximum term of eight years. Option terms are set at the discretion of the CGN Committee of the Board of Directors or the Board of Directors itself, as provided under each plan. At December 31, 2013, approximately 32 million shares were available for future grants under these plans.
Dominion measures and recognizes compensation expense relating to share-based payment transactions over the vesting period based on the fair value of the equity or liability instruments issued. Dominion's results for the years ended December 31, 2013, 2012 and 2011 include $31 million, $25 million, and $39 million, respectively, of compensation costs and $11 million, $8 million, and $13 million, respectively of income tax benefits related to Dominion's stock-based compensation arrangements. Stock-based compensation cost is reported in other operations and maintenance expense in Dominion's Consolidated Statements of Income. Excess tax benefits are classified as a financing cash flow. During the years ended December 31, 2013, 2012, and 2011, Dominion realized less than $1 million, $10 million and $2 million, respectively, of excess tax benefits from the vesting of restricted stock awards and exercise of stock options.
STOCK OPTIONS
The following table provides a summary of changes in amounts of stock options outstanding as of and for the years ended December 31, 2012 and 2011. There were no stock options outstanding in 2013. No options were granted under any plan in 2013, 2012 or 2011.
	Shares		Weighted -			Weighted -	Aggregated
			average			average	Intrinsic
			Exercise Price			Remaining	Value(1)
						Contractual
						Life
	(thousands)					(years)	(millions)
Outstanding and exercisable at December 31, 2010	1,810		$	31.76			20
Exercised	(1,174	)	$	32.46			$	17
Forfeited/expired	(8	)	$	31.57
Outstanding and exercisable at December 31, 2011	628		$	30.81			$	14
Exercised	(622	)	$	30.79			$	13
Forfeited/expired	(6	)	$	32.26
Outstanding and exercisable at December 31, 2012	—		$	—			$	—
-1	Intrinsic value represents the difference between the exercise price of the option and the market value of Dominion's stock.
Dominion issues new shares to satisfy any stock option exercises. Dominion received cash proceeds from the exercise of stock options of approximately $19 million, and $38 million in the years ended December 31, 2012 and 2011, respectively.
RESTRICTED STOCK
Restricted stock grants are made to officers under Dominion's LTIP and may also be granted to certain key non-officer employees from time to time. The fair value of Dominion's restricted stock awards is equal to the closing price of Dominion's stock on the date of grant. New shares are issued for restricted stock awards on the date of grant and generally vest over a three-year service period. The following table provides a summary of restricted stock activity for the years ended December 31, 2013, 2012 and 2011:
	Shares		Weighted
			- average
			Grant Date
			Fair Value
	(thousands)
Nonvested at December 31, 2010	1,476		$	38.2
Granted	299		43.68
Vested	(617	)	40.72
Cancelled and forfeited	(25	)	36.29
Converted from goal-based stock to restricted stock	168		30.99
Nonvested at December 31, 2011	1,301		$	37.37
Granted	390		51.14
Vested	(596	)	33.31
Cancelled and forfeited	(10	)	42.99
Nonvested at December 31, 2012	1,085		$	44.46
Granted	312		54.7
Vested	(356	)	39
Cancelled and forfeited	(34	)	51.11
Nonvested at December 31, 2013	1,007		$	49.35
As of December 31, 2013, unrecognized compensation cost related to nonvested restricted stock awards totaled $21 million and is expected to be recognized over a weighted-average period of 1.8 years. The fair value of restricted stock awards that vested was $20 million, $30 million, and $28 million in 2013, 2012 and 2011, respectively. Employees may elect to have shares of restricted stock withheld upon vesting to satisfy tax withholding obligations. The number of shares withheld will vary for each employee depending on the vesting date fair market value of Dominion stock and the applicable federal, state and local tax withholding rates.
GOAL-BASED STOCK
Goal-based stock awards are granted under Dominion's LTIP to officers who have not achieved a certain targeted level of share ownership, in lieu of cash-based performance grants. Goal-based stock awards may also be made to certain key non-officer employees from time to time. Current outstanding goal-based shares include awards granted to officers in February 2012 and February 2013.
The issuance of awards is based on the achievement of two performance metrics during a two-year period: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. The actual number of shares issued will vary between zero and 200% of targeted shares depending on the level of performance metrics achieved. The fair value of goal-based stock is equal to the closing price of Dominion's stock on the date of grant. Goal-based stock awards granted to key non-officer employees convert to restricted stock at the end of the two-year performance period and generally vest three years from the original grant date. Awards to officers vest at the end of the two-year performance period. All goal-based stock awards are settled by issuing new shares.
After the performance period for the February 2010 grants ended on December 31, 2011, the CGN Committee determined the actual performance against metrics established for those awards. For awards to officers, 9 thousand shares of the outstanding goal-based stock awards were converted to 15 thousand non-restricted shares and issued to the officers.
After the performance period for the February 2011 grants ended on December 31, 2012, the CGN Committee determined the actual performance against metrics established for those awards. For awards to officers, 3 thousand shares of the outstanding goal-based stock awards were converted to 2 thousand non-restricted shares and issued to the officers.
The following table provides a summary of goal-based stock activity for the years ended December 31, 2013, 2012 and 2011:
	Targeted		Weighted
	Number of		- average
	Shares		Grant
			Date Fair
			Value
	(thousands)
Nonvested at December 31, 2010	161		$	31.79
Granted	3		43.54
Vested	(20	)	34.62
Cancelled and forfeited	(132	)	30.99
Nonvested at December 31, 2011	12		$	39.19
Granted	1		52.48
Vested	(9	)	37.46
Nonvested at December 31, 2012	4		$	45.6
Granted	4		54.17
Vested	(2	)	43.54
Cancelled and forfeited	(1	)	43.54
Nonvested at December 31, 2013	5		$	53.85
At December 31, 2013, the targeted number of shares expected to be issued under the February 2012 and February 2013 awards was approximately 5 thousand. In January 2014, the CGN Committee determined the actual performance against metrics established for the February 2012 awards with a performance period that ended December 31, 2013. Based on that determination, the total number of shares to be issued under the February 2012 goal-based stock awards was approximately 1 thousand.
As of December 31, 2013, unrecognized compensation cost related to nonvested goal-based stock awards was not material.
CASH-BASED PERFORMANCE GRANTS
Cash-based performance grants are made to Dominion's officers under Dominion's LTIP. The actual payout of cash-based performance grants will vary between zero and 200% of the targeted amount based on the level of performance metrics achieved.
In February 2010, a cash-based performance grant was made to officers. A portion of the grant, representing $14 million was paid in December 2011, based on the achievement of two performance metrics during 2010 and 2011: ROIC and TSR relative to that of a peer group of companies. The total amount of the award under the grant was $20 million and the remaining $6 million of the grant was paid in February 2012.
In February 2011, a cash-based performance grant was made to officers. A portion of the grant, representing $6 million was paid in December 2012, based on the achievement of two performance metrics during 2011 and 2012: ROIC and TSR relative to that of a peer group of companies. The total amount of the award under the grant was $8 million and the remaining $2 million of the grant was paid in February 2013.
In February 2012, a cash-based performance grant was made to officers. A portion of the grant, representing the initial payout of $8 million was paid in December 2013, based on the achievement of two performance metrics during 2012 and 2013: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. The total expected award under the grant is $12 million and the remaining portion of the grant is expected to be paid by March 15, 2014. At December 31, 2013, a liability of $4 million had been accrued for the remaining portion of the award.
In February 2013, a cash-based performance grant was made to officers. Payout of the performance grant is expected to occur by March 15, 2015 based on the achievement of two performance metrics during 2013 and 2014: TSR relative to that of companies listed as members of the Philadelphia Utility Index as of the end of the performance period and ROIC. At December 31, 2013, the targeted amount of the grant was $13 million and a liability of $6 million had been accrued for this award.

Dividend_Restrictions

Dividend Restrictions	12 Months Ended
	Dec. 31, 2013
Disclosure of Restrictions on Dividends, Loans and Advances Disclosure [Abstract]	'
Dividend Restrictions	'
	DIVIDEND RESTRICTIONS
	The Virginia Commission may prohibit any public service company, including Virginia Power, from declaring or paying a dividend to an affiliate if found to be detrimental to the public interest. At December 31, 2013, the Virginia Commission had not restricted the payment of dividends by Virginia Power.
	Certain agreements associated with Dominion's and Virginia Power's credit facilities contain restrictions on the ratio of debt to total capitalization. These limitations did not restrict Dominion's or Virginia Power's ability to pay dividends or receive dividends from their subsidiaries at December 31, 2013.
	See Note 17 for a description of potential restrictions on dividend payments by Dominion in connection with the deferral of interest payments on junior subordinated notes and equity units, initially in the form of corporate units.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2013
General Discussion of Pension and Other Postretirement Benefits [Abstract]	'
Employee Benefit Plans	'
	EMPLOYEE BENEFIT PLANS
	DOMINION
	Dominion provides certain retirement benefits to eligible active employees, retirees and qualifying dependents. Under the terms of its benefit plans, Dominion reserves the right to change, modify or terminate the plans. From time to time in the past, benefits have changed, and some of these changes have reduced benefits.
	Dominion maintains qualified noncontributory defined benefit pension plans covering virtually all employees. Retirement benefits are based primarily on years of service, age and the employee's compensation. Dominion's funding policy is to contribute annually an amount that is in accordance with the provisions of ERISA. The pension program also provides benefits to certain retired executives under a company-sponsored nonqualified employee benefit plan. The nonqualified plan is funded through contributions to a grantor trust. Dominion also provides retiree healthcare and life insurance benefits with annual employee premiums based on several factors such as age, retirement date and years of service.
	Pension and other postretirement benefit costs are affected by employee demographics (including age, compensation levels and years of service), the level of contributions made to the plans and earnings on plan assets. These costs may also be affected by changes in key assumptions, including expected long-term rates of return on plan assets, discount rates, healthcare cost trend rates and the rate of compensation increases.
	Dominion uses December 31 as the measurement date for all of its employee benefit plans. Dominion uses the market-related value of pension plan assets to determine the expected return on plan assets, a component of net periodic pension cost. The market-related value recognizes changes in fair value on a straight-line basis over a four-year period, which reduces year-to-year volatility. Changes in fair value are measured as the difference between the expected and actual plan asset returns, including dividends, interest and realized and unrealized investment gains and losses. Since the market-related value recognizes changes in fair value over a four-year period, the future market-related value of pension plan assets will be impacted as previously unrecognized changes in fair value are recognized.
	Dominion's pension and other postretirement benefit plans hold investments in trusts to fund employee benefit payments. Aggregate actual returns for Dominion's pension and other postretirement plan assets were $959 million in 2013 and $743 million in 2012, versus expected returns of $554 million and $509 million, respectively. 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 periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash to be contributed to the employee benefit plans.
	The Medicare Act introduced a federal subsidy to sponsors of retiree healthcare benefit plans that provide a prescription drug benefit that is at least actuarially equivalent to Medicare Part D. Dominion determined that the prescription drug benefit offered under its other postretirement benefit plans is at least actuarially equivalent to Medicare Part D. Dominion received a federal subsidy of $5 million for each of 2013 and 2012. Effective January 1, 2013, Dominion changed its method of receiving the subsidy under Medicare Part D for retiree prescription drug coverage from the Retiree Drug Subsidy to the EGWP. This change reduced other postretirement benefit costs by approximately $20 million annually beginning in 2012. As a result of the adoption of the EGWP, Dominion will begin to receive an increased level of Medicare Part D subsidies, in the form of reduced costs rather than a direct reimbursement, over the next few years.
	Dominion remeasured all of its pension and other postretirement benefit plans in the second quarter of 2013. The remeasurement resulted in a reduction in the pension benefit obligation of approximately $354 million and a reduction in the accumulated postretirement benefit obligation of approximately $78 million. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date and reduced net periodic benefit cost for 2013 by approximately $36 million, excluding the impacts of curtailments. The discount rate used for the remeasurement was 4.80% for the pension plans and 4.70% for the other postretirement benefit plans. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2012.
	In the fourth quarter of 2013, Dominion remeasured its other postretirement benefit plans as a result of a plan amendment that changed medical coverage for certain Medicare-eligible retirees effective April 2014. The remeasurement resulted in a reduction in the accumulated postretirement benefit obligation of approximately $220 million. The impact of the remeasurement on net periodic benefit cost (credit) was recognized prospectively from the remeasurement date and reduced net periodic benefit cost for 2013 by approximately $8 million. The amendment is expected to reduce net periodic benefit cost by $40 million to $60 million for each of the next five years. The discount rate used for the remeasurement was 4.80%. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2012.
	Funded Status
	The following table summarizes the changes in Dominion's pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans' funded status:
		Pension Benefits						Other Postretirement
								Benefits
	Year Ended December 31,	2013			2012			2013			2012
	(millions, except percentages)
	Changes in benefit obligation:
	Benefit obligation at beginning of year	$	6,125		$	4,981		$	1,719		$	1,493
	Service cost	131			116			43			44
	Interest cost	271			268			73			79
	Benefits paid	(229		)	(208		)	(75		)	(88		)
	Actuarial (gains) losses during the year	(650		)	967			(170		)	191
	Plan amendments(1)	1			1			(220		)	1
	Settlements and curtailments(2)	(24		)	—			(16		)	(6		)
	Special termination benefits	—			—			1			—
	Medicare Part D reimbursement	—			—			5			5
	Benefit obligation at end of year	$	5,625		$	6,125		$	1,360		$	1,719
	Changes in fair value of plan assets:
	Fair value of plan assets at beginning of year	$	5,553		$	5,145		$	1,156		$	1,042
	Actual return on plan assets	781			611			178			132
	Employer contributions	8			5			12			16
	Benefits paid	(229		)	(208		)	(31		)	(34		)
	Fair value of plan assets at end of year	$	6,113		$	5,553		$	1,315		$	1,156
	Funded status at end of year	$	488		$	(572	)	$	(45	)	$	(563	)
	Amounts recognized in the Consolidated Balance Sheets at December 31:
	Noncurrent pension and other postretirement benefit assets	$	913		$	701		$	29		$	1
	Other current liabilities	(15		)	(2		)	(3		)	(4		)
	Noncurrent pension and other postretirement benefit liabilities	(410		)	(1,271		)	(71		)	(560		)
	Net amount recognized	$	488		$	(572	)	$	(45	)	$	(563	)
	Significant assumptions used to determine benefit obligations as of December 31:
	Discount rate(3)	5.20%/5.30%			4.4		%	5.00%/5.10%			4.4		%
	Weighted average rate of increase for compensation	4.21		%	4.21		%	4.22		%	4.22		%
	-1	Relates to a plan amendment that changed medical coverage for certain Medicare-eligible retirees.
	-2	2013 amounts relate primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.
	-3	Pension rates are 5.20% for the gas union plans and 5.30% for the nonunion and other union plans. OPEB rates are 5.00% for the gas union plans and 5.10% for the nonunion and other union plans.
	The ABO for all of Dominion's defined benefit pension plans was $5.1 billion and $5.5 billion at December 31, 2013 and 2012, respectively.
	Under its funding policies, Dominion evaluates plan funding requirements annually, usually in the fourth quarter after receiving updated plan information from its actuary. Based on the funded status of each plan and other factors, Dominion determines the amount of contributions for the current year, if any, at that time. During 2013, Dominion made no contributions to its qualified defined benefit pension plans and no contributions are currently expected in 2014. In July 2012, the Moving Ahead for Progress in the 21st Century Act was signed into law. This Act includes an increase in the interest rates used to determine plan sponsors' pension contributions for required funding purposes. These new interest rates are expected to reduce required pension contributions through 2015. Dominion believes that required pension contributions will rise subsequent to 2015, resulting in little net impact to cumulative required contributions over a 10-year period.
	Certain regulatory authorities have held that amounts recovered in utility customers' rates for other postretirement benefits, in excess of benefits actually paid during the year, must be deposited in trust funds dedicated for the sole purpose of paying such benefits. Accordingly, certain of Dominion's subsidiaries fund other postretirement benefit costs through VEBAs. Dominion's remaining subsidiaries do not prefund other postretirement benefit costs but instead pay claims as presented. Dominion expects to contribute approximately $12 million to the Dominion VEBAs in 2014.
	Dominion does not expect any pension or other postretirement plan assets to be returned to the Company during 2014.
	The following table provides information on the benefit obligations and fair value of plan assets for plans with a benefit obligation in excess of plan assets:
		Pension Benefits								Other Postretirement
										Benefits
	As of December 31,	2013				2012				2013			2012
	(millions)
	Benefit obligation	$	4,978			$	5,462			$	1,233		$	1,591
	Fair value of plan assets	4,553				4,189				1,158			1,027
	The following table provides information on the ABO and fair value of plan assets for pension plans with an ABO in excess of plan assets:
	As of December 31,	2013			2012
	(millions)
	Accumulated benefit obligation	$	114		$	4,850
	Fair value of plan assets	—			4,189
	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid:
		Estimated Future Benefit Payments
	Pension Benefits			Other  Postretirement Benefits
(millions)
2014	$	264		$	91
2015	269			93
2016	283			96
2017	300			98
2018	319			100
2019-2023	1,868			507
Plan Assets
Dominion's overall objective for investing its pension and other postretirement plan assets is to achieve appropriate long-term rates of return commensurate with prudent levels of risk. To minimize risk, funds are broadly diversified among asset classes, investment strategies and investment advisors. The strategic target asset allocations for its pension funds are 28% U.S. equity, 18% non-U.S. equity, 33% fixed income, 3% real estate and 18% other alternative investments. U.S. equity includes investments in large-cap, mid-cap and small-cap companies located in the United States. Non-U.S. equity includes investments in large-cap and small-cap companies located outside of the United States including both developed and emerging markets. A common/collective trust fund is a pooled fund operated by a bank or trust company for investment of the assets of various organizations and individuals in a well-diversified portfolio. Fixed income includes corporate debt instruments of companies from diversified industries and U.S. Treasuries. The U.S. equity, non-U.S. equity and fixed income investments are in individual securities as well as mutual funds. Common/collective trust funds are funds of grouped assets that follow various investment strategies. Real estate includes equity REITs and investments in partnerships. Other alternative investments include partnership investments in private equity, debt and hedge funds that follow several different strategies.
Strategic investment policies are established for Dominion's prefunded benefit plans based upon periodic asset/liability studies. Factors considered in setting the investment policy include employee demographics, liability growth rates, future discount rates, the funded status of the plans and the expected long-term rate of return on plan assets. Deviations from the plans' strategic allocation are a function of Dominion's assessments regarding short-term risk and reward opportunities in the capital markets and/or short-term market movements which result in the plans' actual asset allocations varying from the strategic target asset allocations. Through periodic rebalancing, actual allocations are brought back in line with the target. Future asset/liability studies will focus on strategies to further reduce pension and other postretirement plan risk, while still achieving attractive levels of returns. Financial derivatives may be used to obtain or manage market exposures and to hedge assets and liabilities.
For fair value measurement policies and procedures related to pension and other postretirement benefit plan assets, see Note 6.
The fair values of Dominion's pension plan assets by asset category are as follows:
	Fair Value Measurements
	Pension Plans
At December 31,	2013												2012
	Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
(millions)
Cash equivalents	$	53		$	126		—			$	179		—			$	195		—			$	195
U.S. equity:
Large Cap	1,220			—			—			1,220			927			104			—			1,031
Other	514			—			—			514			425			99			—			524
Non-U.S. equity:
Large Cap	308			—			—			308			313			68			—			381
Other	391			—			—			391			228			167			—			395
Common/collective trust funds	—			1,387			—			1,387			—			—			—			—
Fixed income:
Corporate debt instruments	43			451			—			494			27			1,026			—			1,053
U.S. Treasury securities and agency debentures	2			229			—			231			331			304			—			635
State and municipal	69			107			—			176			1			71			—			72
Other securities	7			50			—			57			5			43			—			48
Real estate:
REITs	32			—			—			32			29			—			—			29
Partnerships	—			—			227			227			—			—			321			321
Other alternative investments:
Private equity	—			—			530			530			—			—			456			456
Debt	—			—			180			180			—			—			192			192
Hedge funds	—			—			187			187			—			—			221			221
Total	$	2,639		$	2,350		$	1,124		$	6,113		$	2,286		$	2,077		$	1,190		$	5,553
The fair values of Dominion's other postretirement plan assets by asset category are as follows:
	Fair Value Measurements
	Other Postretirement Plans
At December 31,	2013												2012
	Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
(millions)
Cash equivalents	$	3		$	14		$	—		$	17		$	—		$	13		$	—		$	13
U.S. equity:
Large Cap	472			—			—			472			378			5			—			383
Other	26			—			—			26			21			45			—			66
Non-U.S. equity:
Large Cap	111			—			—			111			93			3			—			96
Other	20			—			—			20			11			8			—			19
Common/collective trust funds	—			502			—			502			—			—			—			—
Fixed income:
Corporate debt instruments	2			23			—			25			1			160			—			161
U.S. Treasury securities and agency debentures	—			12			—			12			16			266			—			282
State and municipal	4			5			—			9			—			9			—			9
Other securities	—			3			—			3			—			2			—			2
Real estate:
REITs	2			—			—			2			1			—			—			1
Partnerships	—			—			19			19			—			—			24			24
Other alternative investments:
Private equity	—			—			60			60			—			—			58			58
Debt	—			—			27			27			—			—			31			31
Hedge funds	—			—			10			10			—			—			11			11
Total	$	640		$	559		$	116		$	1,315		$	521		$	511		$	124		$	1,156
The following table presents the changes in Dominion's pension and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category:
	Fair Value Measurements using Significant Unobservable Inputs (Level 3)
	Pension Plans															Other Postretirement Plans
	Real Estate			Private Equity			Debt			Hedge Funds			Total			Real Estate			Private Equity			Debt			Hedge Funds			Total
Balance at December 31, 2010	$	271		$	400		$	262		$	345		$	1,278		$	22		$	61		$	40		$	17		$	140
Actual return on plan assets:
Relating to assets still held at the reporting date	38			70			10			10			128			3			11			1			—			15
Relating to assets sold during the period	(8		)	(34		)	(10		)	(15		)	(67		)	—			(4		)	(1		)	(1		)	(6		)
Purchases	57			76			34			48			215			3			8			3			2			16
Sales	(54		)	(64		)	(53		)	(98		)	(269		)	(4		)	(13		)	(7		)	(4		)	(28		)
Balance at December 31, 2011	$	304		$	448		$	243		$	290		$	1,285		$	24		$	63		$	36		$	14		$	137
Actual return on plan assets:
Relating to assets still held at the reporting date	21			46			17			21			105			1			3			4			1			9
Relating to assets sold during the period	(8		)	(41		)	(11		)	(2		)	(62		)	—			(1		)	—			—			(1		)
Purchases	35			79			15			—			129			2			6			1			—			9
Sales	(31		)	(76		)	(72		)	(88		)	(267		)	(3		)	(13		)	(10		)	(4		)	(30		)
Balance at December 31, 2012	$	321		$	456		$	192		$	221		$	1,190		$	24		$	58		$	31		$	11		$	124
Actual return on plan assets:
Relating to assets still held at the reporting date	15			98			32			21			166			(2		)	6			3			1			8
Relating to assets sold during the period	(36		)	(48		)	(34		)	(4		)	(122		)	1			3			—			1			5
Purchases	6			115			32			—			153			1			7			2			—			10
Sales	(79		)	(91		)	(42		)	(51		)	(263		)	(5		)	(14		)	(9		)	(3		)	(31		)
Balance at December 31, 2013	$	227		$	530		$	180		$	187		$	1,124		$	19		$	60		$	27		$	10		$	116
Investments in Common/Collective Trust Funds in Dominion’s pension and other postretirement plans are stated at fair value as determined by the issuer of the Common/Collective Trust Funds based on the fair value of the underlying investments. The Common/Collective Trusts do not have any unfunded commitments, and do not have any applicable liquidation periods or defined terms/periods to be held. The majority of the Common/Collective Trust Funds have limited withdrawal or redemption rights during the term of the investment. Strategies of the Common/Collective Trust Funds are as follows:
•	Wells Fargo Closed End Bond Trust-The Fund invests in stocks, bonds or a combination of both. Shares of the Fund are traded on a stock exchange and are subject to market risk like stocks, bonds and mutual funds. The Fund may invest in a less liquid portfolio of stocks and bonds because the fund does not need to sell securities to meet shareholder redemptions as mutual funds in order to keep a percentage of its portfolio in cash to pay back investors who withdraw shares.
•	JPMorgan Core Bond Trust-The Fund seeks to maximize total return by investing primarily in a diversified portfolio of intermediate- and long-term debt securities. The Fund invests primarily in investment-grade bonds; it generally maintains an average weighted maturity between four and 12 years. It may shorten its average weighted maturity if deemed appropriate for temporary defensive purposes.
•	SSgA Russell 2000 Value Index Common Trust-The Fund measures the performance of the small-cap value segment of the U.S. equity universe. The Russell 2000 Value Index is constructed to provide a comprehensive and unbiased barometer for the small-cap value segment. The Index is completely reconstituted annually to ensure larger stocks do not distort the performance and characteristics of the true small-cap opportunity set and that the represented companies continue to reflect value characteristics.
•	SSgA Daily MSCI Emerging Markets Index Non-Lending Fund-The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of the MSCI Emerging Markets Index over the long term. The Fund may invest directly or indirectly in securities and other instruments, including in other pooled investment vehicles sponsored or managed by, or otherwise affiliated with the Trustee (State Street Bank and Trust Company).
•	SSgA Daily MSCI ACWI Ex-USA Index Non-Lending Fund-The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of the MSCI ACWI Ex-USA Index over the long term. The Fund may invest directly or indirectly in securities and other instruments, including in other pooled investment vehicles sponsored or managed by, or otherwise affiliated with the Trustee (State Street Bank and Trust Company).
•	SSgA S&P 400 MidCap Index - The Fund seeks an investment return that approximates as closely as practicable, before expenses, the performance of its benchmark index (the Index) over the long term.  The S&P MidCap 400 is comprised of approximately 400 U.S. mid-cap securities and accounts for approximately 7% coverage of the U.S. stock market capitalization. SSgA will typically attempt to invest in the equity securities comprising the Index, in approximately the same proportions as they are represented in the Index.
•	JPMorgan Chase Bank U.S. Active Core Plus Equity Fund-The Fund seeks to outperform the S&P 500 Index (the Benchmark), gross of fees, over a market cycle. The Fund invests primarily in a portfolio of long and short positions in equity securities of large and mid capitalization U.S. companies with characteristics similar to those of the Benchmark.
•	Mondrian International Small Cap Equity Fund-The Fund’s investment objective is long-term total return. The Fund primarily invests in equity securities of non-U.S. small capitalization companies that, in the investment manager’s opinion, are undervalued at the time of purchase based on fundamental value analysis employed by the investment manager.
Net Periodic Benefit Cost
The components of the provision for net periodic benefit cost and amounts recognized in other comprehensive income and regulatory assets and liabilities are as follows:
	Pension Benefits									Other Postretirement Benefits
Year Ended December 31,	2013			2012			2011			2013			2012			2011
(millions, except percentages)
Service cost	$	131		$	116		$	108		$	43		$	44		$	48
Interest cost	271			268			258			73			79			94
Expected return on plan assets	(462		)	(430		)	(440		)	(92		)	(79		)	(79		)
Amortization of prior service (credit) cost	3			3			3			(15		)	(13		)	(13		)
Amortization of net actuarial loss	165			132			96			7			6			12
Settlements and curtailments(1)	(2		)	—			—			(15		)	(4		)	1
Special termination benefits	—			—			—			1			—			—
Net periodic benefit cost	$	106		$	89		$	25		$	2		$	33		$	63
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
Current year net actuarial (gain) loss	$	(968	)	$	786		$	534		$	(255	)	$	139		$	(157	)
Prior service (credit) cost	1			—			—			(215		)	1			(70		)
Settlements and curtailments(1)	(22		)	—			—			(7		)	(2		)	(1		)
Less amounts included in net periodic benefit cost:
Amortization of net actuarial loss	(165		)	(132		)	(96		)	(7		)	(6		)	(12		)
Amortization of prior service credit (cost)	(3		)	(3		)	(3		)	15			13			13
Total recognized in other comprehensive income and regulatory assets and liabilities	$	(1,157	)	$	651		$	435		$	(469	)	$	145		$	(227	)
Significant assumptions used to determine periodic cost:
Discount rate	4.40% - 4.80%			5.5		%	5.9		%	4.40% - 4.80%			5.5		%	5.9		%
Expected long-term rate of return on plan assets	8.5		%	8.5		%	8.5		%	7.75		%	7.75		%	7.75		%
Weighted average rate of increase for compensation	4.21		%	4.21		%	4.61		%	4.22		%	4.22		%	4.62		%
Healthcare cost trend rate(2)										7		%	7		%	7		%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)(2)										4.6		%	4.6		%	4.6		%
Year that the rate reaches the ultimate trend rate(2)										2062			2061			2060
-1	2013 amount relates primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.
-2	Assumptions used to determine periodic cost for the following year.
The components of AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost are as follows:
	Pension Benefits						Other
							Postretirement
							Benefits
At December 31,	2013			2012			2013			2012
(millions)
Net actuarial (gain) loss	$	1,709		$	2,865		$	(40	)	$	229
Prior service (credit) cost	10			11			(271		)	(71		)
Total(1)	$	1,719		$	2,876		$	(311	)	$	158
-1	As of December 31, 2013, of the $1.7 billion and $(311) million related to pension benefits and other postretirement benefits, $1.0 billion and $(156) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2012, of the $2.9 billion and $158 million related to pension benefits and other postretirement benefits, $1.8 billion and $69 million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.
The following table provides the components of AOCI and regulatory assets and liabilities as of December 31, 2013 that are expected to be amortized as components of periodic benefit cost in 2014:
	Pension			Other
	Benefits			Postretirement
				Benefits
(millions)
Net actuarial loss	$	112		$	2
Prior service (credit) cost	3			(28		)
Dominion determines the expected long-term rates of return on plan assets for its pension plans and other postretirement benefit plans by using a combination of:
•	Expected inflation and risk-free interest rate assumptions;
•	Historical return analysis to determine long term historic returns as well as historic risk premiums for various asset classes;
•	Expected future risk premiums, asset volatilities and correlations;
•	Forecasts of an independent investment advisor;
•	Forward-looking return expectations derived from the yield on long-term bonds and the expected long-term returns of major stock market indices; and
•	Investment allocation of plan assets.
Dominion determines discount rates from analyses of AA/Aa rated bonds with cash flows matching the expected payments to be made under its plans.
Assumed healthcare cost trend rates have a significant effect on the amounts reported for Dominion's retiree healthcare plans. A one percentage point change in assumed healthcare cost trend rates would have had the following effects:
	Other Postretirement Benefits
	One percentage point increase			One percentage point decrease
(millions)
Effect on net periodic cost for 2014	$	16		$	(18	)
Effect on other postretirement benefit obligation at December 31, 2013	140			(118		)
An internal committee selects the final assumptions used for Dominion's pension and other postretirement plans, including discount rates, expected long-term rates of return and healthcare cost trend rates.
Defined Contribution Plans
In addition, Dominion sponsors defined contribution employee savings plans. During 2013, 2012 and 2011, Dominion recognized $40 million, $40 million and $38 million, respectively, as employer matching contributions to these plans.
VIRGINIA POWER
Virginia Power participates in the Dominion Pension Plan, a defined benefit pension plan sponsored by Dominion that provides benefits to multiple Dominion subsidiaries. Retirement benefits payable under this plan are based primarily on years of service, age and the employee's compensation. As a participating employer, Virginia Power is subject to Dominion's funding policy, which is to contribute annually an amount that is in accordance with the provisions of ERISA. During 2013 and 2012 Virginia Power made no contributions to the plan and no contributions are currently expected in 2014. Virginia Power's net periodic pension cost related to this pension plan was $96 million, $72 million and $50 million in 2013, 2012 and 2011, respectively. Employee compensation is the basis for determining Virginia Power's share of total pension costs.
Virginia Power also participates in the Dominion Retiree Health and Welfare Plan, a plan sponsored by Dominion that provides certain retiree healthcare and life insurance benefits to multiple Dominion subsidiaries. Annual employee premiums are based on several factors such as age, retirement date and years of service. Virginia Power's net periodic benefit cost related to this plan was $5 million, $13 million and $23 million in 2013, 2012 and 2011, respectively. Employee headcount is the basis for determining Virginia Power's share of total other postretirement benefit costs.
Certain regulatory authorities have held that amounts recovered in rates for other postretirement benefits, in excess of benefits actually paid during the year, must be deposited in trust funds dedicated for the sole purpose of paying such benefits. Accordingly, Virginia Power funds other postretirement benefit costs through a VEBA. During 2013 and 2012, Virginia Power made no contributions to the VEBA and does not expect to contribute to the VEBA in 2014.
Dominion holds investments in trusts to fund employee benefit payments for its pension and other postretirement benefit plans, in which Virginia Power's employees participate. Any investment-related declines in these trusts will result in future increases in the periodic cost recognized for such employee benefit plans and will be included in the determination of the amount of cash that Virginia Power will provide to Dominion for its share of employee benefit plan contributions.
Virginia Power also participates in Dominion-sponsored defined contribution employee savings plans that cover substantially all employees. During 2013, 2012 and 2011, Virgina Power recognized $16 million, $15 million and $14 million, respectively, as employer matching contributions to these plans.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	COMMITMENTS AND CONTINGENCIES
	As a result of issues generated in the ordinary course of business, Dominion and Virginia Power are involved in legal proceedings before various courts and are periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for the Companies to estimate a range of possible loss. For such matters that the Companies cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that the Companies are able to estimate a range of possible loss. For legal proceedings and governmental examinations 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 Dominion's or Virginia Power's financial position, liquidity or results of operations.
	Environmental Matters
	Dominion and Virginia Power 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
	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 Dominion's and Virginia Power's facilities are subject to the CAA's permitting and other requirements.
	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 will be required by April 16, 2015, with certain limited exceptions. In December 2011, Virginia Power recorded a $228 million ($139 million after-tax) charge reflecting plant balances that are not expected to be recovered in future periods due to the anticipated retirement of certain regulated coal units, primarily as a result of the issuance of the final MATS. During the fourth quarter of 2013, Virginia Power recorded charges totaling $26 million ($16 million after-tax) for certain exit activities associated with these coal units, including the cost of employee severance, vendor contract termination, and inventory not expected to be used or usable at other stations.
	The EPA established CAIR with the intent to require significant reductions in SO2 and NOX emissions from electric generating facilities. In July 2008, the U.S. Court of Appeals for the D.C. 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 NOx emissions cap and trade programs that were completely independent of the current ARP. Specifically, CSAPR required reductions in SO2 and NOx emissions from fossil fuel-fired electric generating units of 25 MW or more through annual NOx emissions caps, NOx 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.
	Following numerous petitions by industry participants for review and motions for stay, the U.S. Court of Appeals for the D.C. Circuit issued a ruling in December 2011 to stay CSAPR pending judicial review. In February and June 2012, the EPA issued technical revisions to CSAPR that were not material to Dominion. In August 2012, the court vacated CSAPR in its entirety and ordered the EPA to implement CAIR until a valid replacement rule is issued. In October 2012, the EPA filed a petition requesting a rehearing of the court's decision, which was denied in January 2013. The mandate vacating CSAPR was issued in February 2013. In March 2013, the EPA and several environmental groups filed petitions with the U.S. Supreme Court requesting review of the decision to vacate and remand CSAPR. In June 2013, the U.S. Supreme Court granted the EPA's petition seeking review of the D.C. Circuit's decision that vacated and remanded CSAPR. With respect to Dominion's generation fleet, the cost to comply with CAIR is not expected to be material. Future outcomes of litigation and/or any additional action to issue a revised rule could affect the assessment regarding cost of compliance.
	In May 2012, the EPA issued final designations for the 75-ppb ozone air quality standard. Several Dominion electric generating facilities are located in areas impacted by this standard. As part of the standard, states will be required to develop and implement plans to address sources emitting pollutants which contribute to the formation of ozone. Until the states have developed implementation plans, Dominion is unable to predict whether or to what extent the new rules will ultimately require additional controls.
	In February 2008, Dominion received a request for information pursuant to Section 114 of the CAA from the EPA. The request concerned historical operating changes and capital improvements undertaken at State Line and Kincaid. In April 2009, Dominion received a second request for information. Dominion provided information in response to both requests. Also in April 2009, Dominion received a Notice and Finding of Violations from the EPA claiming violations of the CAA New Source Review requirements, NSPS, the Title V permit program and the stations' respective State Implementation Plans. In May 2010, Dominion received a request for information pursuant to Section 114 of the CAA from the EPA. The request concerned historical operating changes and capital improvements undertaken at Brayton Point.
	Dominion believes that it complied with applicable laws and the EPA regulations and interpretations in effect at the time the work in question took place. Dominion entered into settlement discussions with the U.S. government and reached an agreement to settle the allegations. In April 2013, the U.S. government lodged a consent decree and complaint with the U.S. District Court for the Central District of Illinois that resolves all alleged violations at State Line, Kincaid and Brayton Point. The settlement mandates the closure of State Line, installation of certain control technology at Kincaid and Brayton Point, the achievement of certain emissions limitations, payment of a civil penalty of $3 million and funding of $10 million in environmental mitigation projects. In July 2013, the court entered the consent decree, concluding the enforcement action. Dominion previously accrued a liability of $13 million related to this matter.  State Line ceased operations in March 2012 and was sold in June 2012.  The installation of pollution control technology was in progress at Kincaid and had been completed at Brayton Point. In August 2013, Dominion sold Kincaid and Brayton Point. Under the terms of the sale transaction, Dominion retained the $13 million liability associated with the settlement agreement. Dominion has paid the civil penalty and is implementing the environmental mitigation projects.
	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. Dominion and Virginia Power must comply with applicable aspects of the CWA programs at their operating facilities.
	In September 2010, Millstone's NPDES permit was reissued under the CWA. The conditions of the permit require an evaluation of control technologies that could result in additional expenditures in the future. The report summarizing the results of the evaluation was submitted in August 2012 and is under review by the Connecticut Department of Energy and Environmental Protection. Dominion cannot currently predict the outcome of this review. In October 2010, the permit issuance was appealed to the state court by a private plaintiff. The permit is expected to remain in effect during the appeal. Dominion is currently unable to make an estimate of the potential financial statement impacts related to this matter.
	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 U.S. government either to clean up sites at which hazardous substances have created actual or potential environmental hazards or to order persons responsible for the situation to do so. Under the CERCLA, as amended, generators and transporters of hazardous substances, as well as past and present owners and operators of contaminated sites, can be jointly, severally and strictly liable for the cost of cleanup. These potentially responsible parties can be ordered to perform a cleanup, be sued for costs associated with an EPA-directed cleanup, voluntarily settle with the U.S. government concerning their liability for cleanup costs, or voluntarily begin a site investigation and site remediation under state oversight.
	From time to time, Dominion or Virginia Power 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 or Virginia Power 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. 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 Dominion and Virginia Power 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. Dominion 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. A remedy has not been selected. Due to the uncertainty surrounding the other sites, Dominion is unable to make an estimate of the potential financial statement impacts.
	CLIMATE CHANGE LEGISLATION AND REGULATION
	Massachusetts, Rhode Island, Connecticut, and Maryland, among other states, have joined RGGI, a multi-state effort to reduce CO2 emissions in the Northeast implemented through state specific regulations. Under the initiative, aggregate CO2 emissions from power plants in participating states are required to be stabilized at current levels from 2009 to 2015. Further reductions from current levels would be required to be phased in starting in 2016 such that by 2019 there would be a 10% reduction in participating state power plant CO2 emissions. During 2012, RGGI underwent a program review, and in February 2013, revisions to the RGGI model rule were issued that include a reduction of the regional CO2 emissions cap from 165 million tons to 91 million tons beginning in January 2014, with an additional 2.5% reduction per year through 2020. The revisions also include changes to compliance demonstration requirements for regulated entities, offset and cost containment mechanisms. Most of the RGGI states have completed the regulatory and/or legislative processes required to amend existing state regulations to implement the RGGI program changes. However, as a result of the recent sales of several power plants located in these states, Dominion does not expect that RGGI will have a material effect on operations, financial condition, and/or cash flows.
	In December 2009, the EPA issued their Final Endangerment and Cause or Contribute Findings for Greenhouse Gases under Section 202(a) of the Clean Air Act, finding that GHGs “endanger both the public health and the public welfare of current and future generations.” On April 1, 2010, the EPA and the Department of Transportation's National Highway Safety Administration announced a joint final rule establishing a program that will dramatically reduce GHG emissions and improve fuel economy for new cars and trucks sold in the United States. These rules took effect in January 2011 and established GHG emissions as regulated pollutants under the CAA.
	In May 2010, the EPA issued the Final Prevention of Significant Deterioration and Title V Greenhouse Gas Tailoring Rule that, combined with prior actions, require Dominion and Virginia Power to obtain permits for GHG emissions for new and modified facilities over certain size thresholds, and meet best available control technology for GHG emissions. The EPA has issued draft guidance for GHG permitting, including best available control technology.
	In April 2012, the EPA published proposed NSPS for GHG emissions for new electric generating units. This proposed rule set national emission standards for new coal, oil, integrated gasification, and combined cycle units larger than 25MW. The
	proposed rule covered CO2 only and does not apply to existing sources. The proposed rule also does not apply to any new or
	existing biomass units. In June 2013, the President of the U.S. released a Climate Action Plan focusing on ways to meet the national GHG reduction goal of 17% from 2005 levels by 2020. Pursuant to the Presidential Memorandum issued in conjunction with the Climate Action Plan, the EPA withdrew the April 2012 proposal and re-proposed the NSPS standards for new sources on January 8, 2014 and is expected to finalize the rule in 2014 or early 2015. The Presidential Memorandum also directed the EPA to propose a rule for reconstructed, modified and existing sources of GHG emissions no later than June 2014, and issue a final rule no later than June 2015, to provide guidelines to the states to achieve the required GHG reductions. Dominion currently cannot predict with certainty the direct or indirect financial impact on operations from these rule revisions, but believes the expenditures to comply with any new requirements could be material.
	In October 2013, the U.S. Supreme Court granted petitions filed by several industry groups, states, and the Chamber of Commerce seeking review of the D.C. Circuit Court's June 2012 decision upholding the EPA’s regulation of GHG under the CAA. The court’s decision could potentially impact EPA's continued implementation of current Prevention of Significant Deterioration regulations applicable to stationary sources in relation to GHG. It is not anticipated, however, that the court's decision would affect the EPA’s development of the GHG NSPS rules for new sources, or existing sources, as the authority for those rules comes from a different section of the CAA than what is at issue in the Supreme Court case. It is uncertain at this time whether the court’s decision will have any material impact on Dominion's operations.
	In July 2011, the EPA signed a final rule deferring the need for Prevention of Significant Deterioration and Title V permitting for CO2 emissions for biomass projects. This rule temporarily deferred for a period of up to 3 years the consideration of CO2 emissions from biomass projects when determining whether a stationary source meets the Prevention of Significant Deterioration and Title V applicability thresholds, including those for the application of best available control technology.  In July 2013, the U.S. Court of Appeals for the D.C. 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 will affect biomass sources that were permitted during the deferral period, however the expenditures to comply with any new requirements could be material.
	Natrium and Blue Racer
	In January 2011, Dominion announced the development of a natural gas processing and fractionation facility in Natrium, West Virginia, and in July 2011 it executed a contract for the construction of the first phase of the facility. The first phase of the project is fully contracted and was placed into service in May 2013. In August 2013, the Natrium natural gas processing and fractionation facility was contributed to the Blue Racer joint venture. In September 2013, the Natrium facility was shut down following a fire at the plant. It returned to service in January 2014. There was no material impact on Dominion’s financial condition, results of operations, and/or cash flows.
	MF Global
	Prior to October 31, 2011, certain of Dominion's subsidiaries executed certain commodity transactions on exchanges using MF Global, an FCM registered with the CFTC. In order to secure its potential exposure on these commodity transactions, Dominion posted certain required margin collateral with MF Global. The parent company of MF Global, MF Global Holdings Ltd., filed for bankruptcy relief under Chapter 11 of the U.S. Bankruptcy Code on October 31, 2011. On the same date, the U.S. District Court for the Southern District of New York appointed a trustee to oversee the liquidation of MF Global pursuant to the Securities Investor Protection Act.
	In accordance with court-approved procedures, Dominion transferred to other FCMs all open positions executed using MF Global. The initial margin posted for these open positions at October 31, 2011 was approximately $73 million. Dominion had received approximately $17 million of this amount through the liquidation process as of December 31, 2012.  In January 2013, Dominion sold the remaining claims of approximately $56 million to a third party at a small discount.
	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 INPO. Like other U.S. 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 require 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. The orders require prompt implementation of the safety enhancements and completion of implementation within two refueling outages or by December 31, 2016, whichever comes first. Implementation of these enhancements is currently in progress. The information requests issued by the NRC request each reactor to reevaluate the seismic and 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. Dominion and Virginia Power do not currently expect that compliance with the NRC's March 2012 orders and information requests will materially impact their financial position, results of operations or cash flows during the approximately four-year implementation period. The NRC staff is evaluating the implementation of the longer term Tier 2 and Tier 3 recommendations. Dominion and Virginia Power are currently unable to estimate the potential financial impacts related to compliance with Tier 2 and Tier 3 recommendations.
	Nuclear Operations
	Nuclear Decommissioning - Minimum Financial Assurance
	The NRC requires nuclear power plant owners to annually update minimum financial assurance amounts for the future decommissioning of their nuclear facilities. Decommissioning involves the decontamination and removal of radioactive contaminants from a nuclear power station once operations have ceased, in accordance with standards established by the NRC. The 2013 calculation for the NRC minimum financial assurance amount, aggregated for Dominion's and Virginia Power's nuclear units, excluding joint owners' assurance amounts and Millstone Unit 1 and Kewaunee, as those units are in a decommissioning state, was $2.8 billion and $1.8 billion, respectively, and has been satisfied by a combination of the funds being collected and deposited in the nuclear decommissioning trusts and the real annual rate of return growth of the funds allowed by the NRC. The 2013 NRC minimum financial assurance amounts above were calculated using preliminary December 31, 2013 U.S. Bureau of Labor Statistics indices. Dominion believes that the amounts currently available in its decommissioning trusts and their expected earnings will be sufficient to cover expected decommissioning costs for the Millstone and Kewaunee units. Virginia Power also believes that the decommissioning funds and their expected earnings for the Surry and North Anna units will be sufficient to cover expected decommissioning costs, particularly when combined with future ratepayer collections and contributions to these decommissioning trusts, if such future collections and contributions are required. This reflects a positive long-term outlook for trust fund investment returns as the decommissioning of the units will not be complete for decades. Dominion and Virginia Power will continue to monitor these trusts to ensure they meet the NRC minimum financial assurance requirement, which may include, if needed, the use of parent company guarantees, surety bonding or other financial guarantees recognized by the NRC. See Note 6 to the Consolidated Financial Statements for additional information on Kewaunee.
	Nuclear Insurance
	The Price-Anderson Amendments Act of 1988 provides the public up to $13.6 billion of liability protection per nuclear incident, via obligations required of owners of nuclear power plants, and allows for an inflationary provision adjustment every five years. Dominion and Virginia Power have purchased $375 million of coverage from commercial insurance pools for each reactor site with the remainder provided through a mandatory industry retrospective rating plan. In the event of a nuclear incident at any licensed nuclear reactor in the U.S., the Companies could be assessed up to $127 million for each of their licensed reactors not to exceed $19 million per year per reactor. There is no limit to the number of incidents for which this retrospective premium can be assessed.
	Effective June 7, 2013 for Kewaunee and July 1, 2013 for Millstone and Virginia Power's nuclear units, the levels of nuclear property insurance coverage were reduced to the following:
		Coverage
	(billions)
	Dominion
	Millstone	$	1.7
	Kewaunee	1.06
	Virginia Power(1)
	Surry	$	1.7
	North Anna	1.7
	-1	Surry and North Anna share a blanket property limit of $450 million.
	The Companies' nuclear property insurance coverage for Millstone, Surry and North Anna exceeds the NRC minimum requirement for nuclear power plant licensees of $1.06 billion per reactor site. Kewaunee meets the NRC minimum requirement of $1.06 billion. This includes coverage for premature decommissioning and functional total loss. The NRC requires that the proceeds from this insurance be used first, to return the reactor to and maintain it in a safe and stable condition and second, to decontaminate the reactor and station site in accordance with a plan approved by the NRC. Nuclear property insurance is provided by NEIL, a mutual insurance company, and is subject to retrospective premium assessments in any policy year in which losses exceed the funds available to the insurance company. Dominion's and Virginia Power's maximum retrospective premium assessment for the current policy period is $71 million and $39 million, respectively. Based on the severity of the incident, the Board of Directors of the nuclear insurer has the discretion to lower or eliminate the maximum retrospective premium assessment. Dominion and Virginia Power have the financial responsibility for any losses that exceed the limits or for which insurance proceeds are not available because they must first be used for stabilization and decontamination.
	Millstone and Virginia Power also purchase accidental outage insurance from NEIL to mitigate certain expenses, including replacement power costs, associated with the prolonged outage of a nuclear unit due to direct physical damage. Under this program, the Companies are subject to a retrospective premium assessment for any policy year in which losses exceed funds available to NEIL. Dominion's and Virginia Power's maximum retrospective premium assessment for the current policy period is $19 million and $9 million, respectively.
	During 2013, Kewaunee ceased power production and commenced decommissioning activities.  Effective February 1, 2013, Kewaunee's accidental outage policy for replacement power costs was canceled.
	ODEC, a part owner of North Anna, and Massachusetts Municipal and Green Mountain, part owners of Millstone's Unit 3, are responsible to Dominion and Virginia Power for their share of the nuclear decommissioning obligation and insurance premiums on applicable units, including any retrospective premium assessments and any losses not covered by insurance.
	Spent Nuclear Fuel
	Dominion and Virginia Power entered into contracts with the DOE for the disposal of spent nuclear fuel under provisions of the Nuclear Waste Policy Act of 1982. The DOE failed to begin accepting the spent fuel on January 31, 1998, the date provided by the Nuclear Waste Policy Act and by the Companies' contracts with the DOE. The Companies have previously received damages award payments and settlement payments related to these contracts.
	In 2012, Dominion and Virginia Power resolved additional claims for damages incurred at Millstone, Kewaunee, Surry and North Anna with the Authorized Representative of the Attorney General. The Companies entered into settlement agreements that resolved claims for damages incurred through December 31, 2010, and also provide for periodic payments after that date for damages incurred through December 31, 2013. Initial settlement payments in the amounts of $20 million for Millstone, $6 million for Kewaunee and $75 million for Surry and North Anna were received in the fourth quarter of 2012. In the fourth quarter of 2013, Dominion received payment of approximately $5 million for resolution of claims incurred at Millstone for the period January 1, 2011 through June 30, 2012. The government has formally accepted an offer of settlement for resolution of claims incurred at Kewaunee in the amount of approximately $2 million for the period January 1, 2011 through December 31, 2012, and payment is expected in the first quarter of 2014. By mutual agreement of the parties, the settlement agreements are extendable to provide for resolution of damages incurred after 2013.
	The Companies continue to recognize receivables for certain spent nuclear fuel-related costs that they believe are probable of recovery from the DOE. Dominion's receivables for spent nuclear fuel-related costs totaled $79 million and $36 million at December 31, 2013 and 2012, respectively. Virginia Power's receivables for spent nuclear fuel-related costs totaled $50 million and $26 million at December 31, 2013 and 2012, respectively.
	Pursuant to a November 2013 decision of the U.S Court of Appeals for the District of Columbia Circuit, in January 2014 the Secretary of the DOE sent a recommendation to the U.S. Congress to adjust to zero the current fee of $1 per MWh for electricity paid by civilian nuclear power generators for disposal of spent nuclear fuel. The government continues to pursue further judicial review of the November 2013 decision and until such time as the processes specified in the Nuclear Waste Policy Act for adjustment of the fee are completed, civilian nuclear power generators, including the Companies, are required to pay the waste fee. In 2013, Dominion and Virginia Power recognized fees of $44 million and $27 million, respectively.
The Companies will continue to manage their spent fuel until it is accepted by the DOE.
Long-Term Purchase Agreements
At December 31, 2013, Virginia Power had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that third parties have used to secure financing for the facilities that will provide the contracted goods or services:
	2014		2015		2016		2017		2018		Thereafter		Total
(millions)
Purchased electric capacity(1)	$	336	$	316	$	253	$	159	$	104	$	163	$	1,331
-1	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities and independent power producers, the last of which ends in 2021. Capacity payments under the contracts are generally based on fixed dollar amounts per month, subject to escalation using broad-based economic indices. At December 31, 2013, the present value of Virginia Power's total commitment for capacity payments is $1.1 billion. Capacity payments totaled $345 million, $337 million, and $338 million, and energy payments totaled $236 million, $214 million, and $275 million for 2013, 2012 and 2011, respectively.
Lease Commitments
Dominion and Virginia Power lease various facilities, vehicles and equipment primarily under operating leases. Payments under certain leases are escalated based on an index such as the consumer price index. Future minimum lease payments under noncancelable operating and capital leases that have initial or remaining lease terms in excess of one year as of December 31, 2013 are as follows:
	2014		2015		2016		2017		2018		Thereafter		Total
(millions)
Dominion	$	63	$	60	$	51	$	43	$	37	$	87	$	341
Virginia Power	$	27	$	26	$	21	$	17	$	14	$	27	$	132
Rental expense for Dominion totaled $101 million, $112 million, and $155 million for 2013, 2012 and 2011, respectively. Rental expense for Virginia Power totaled $42 million, $48 million, and $50 million for 2013, 2012, and 2011, respectively. The majority of rental expense is reflected in other operations and maintenance expense in the Consolidated Statements of Income.
Guarantees, Surety Bonds and Letters of Credit
DOMINION
At December 31, 2013, Dominion had issued $69 million of guarantees, primarily to support equity method investees. No significant amounts related to these guarantees have been recorded. As of December 31, 2013, Dominion's exposure under these guarantees was $39 million, primarily related to certain reserve requirements associated with non-recourse financing.
In addition to the above guarantees, Dominion and its partners, Shell and BP, may be required to make additional periodic equity contributions to NedPower and Fowler Ridge in connection with certain funding requirements associated with their respective non-recourse financings. As of December 31, 2013, Dominion's maximum remaining cumulative exposure under these equity funding agreements is $90 million through 2019 and its maximum annual future contributions could range from approximately $4 million to $19 million.
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 December 31, 2013, Dominion had issued the following subsidiary guarantees:
	Stated Limit		Value(1)
(millions)
Subsidiary debt(2)	$	27	$	27
Commodity transactions(3)	3,158		403
Nuclear obligations(4)	232		68
Cove Point(5)	335		—
Other(6)	669		108
Total	$	4,421	$	606
-1	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2013 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 energy trading and marketing activities and other commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power 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 and Kewaunee, respectively, in the event of a prolonged outage, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee also provides for funds through the completion of decommissioning.
-5	Guarantees related to Cove Point, including agreements to support terminal service and transportation agreements as well as an engineering, procurement and construction contract for new liquefaction facilities. Includes certain guarantees that do not have stated limits.
-6	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.
Additionally, as of December 31, 2013 Dominion had purchased $147 million of surety bonds and authorized the issuance of letters of credit by financial institutions of $11 million to facilitate commercial transactions by its subsidiaries with third parties. Under the terms of surety bonds, Dominion is obligated to indemnify the respective surety bond company for any amounts paid.
VIRGINIA POWER
As of December 31, 2013, Virginia Power had issued $14 million of guarantees primarily to support tax-exempt debt issued through conduits. Virginia Power had also purchased $59 million of surety bonds for various purposes, including providing workers' compensation coverage, and authorized the issuance of letters of credit by financial institutions of $1 million to facilitate commercial transactions by its subsidiaries with third parties. Under the terms of surety bonds, Virginia Power is obligated to indemnify the respective surety bond company for any amounts paid.
Indemnifications
As part of commercial contract negotiations in the normal course of business, Dominion and Virginia Power may sometimes agree to make payments to compensate or indemnify other parties for possible future unfavorable financial consequences resulting from specified events. The specified events may involve an adverse judgment in a lawsuit or the imposition of additional taxes due to a change in tax law or interpretation of the tax law. Dominion and Virginia Power are unable to develop an estimate of the maximum potential amount of future payments under these contracts because events that would obligate them have not yet occurred or, if any such event has occurred, they have not been notified of its occurrence. However, at December 31, 2013, Dominion and Virginia Power believe future payments, if any, that could ultimately become payable under these contract provisions, would not have a material impact on their results of operations, cash flows or financial position.

Credit_Risk

Credit Risk	12 Months Ended
	Dec. 31, 2013
Risks and Uncertainties [Abstract]	'
Credit Risk	'
	CREDIT RISK
	Credit risk is the risk of financial loss if counterparties fail to perform their contractual obligations. In order to minimize overall credit risk, credit policies are maintained, including the evaluation of counterparty financial condition, collateral requirements and the use of standardized agreements that facilitate the netting of cash flows associated with a single counterparty. In addition, counterparties may make available collateral, including letters of credit or cash held as margin deposits, as a result of exceeding agreed-upon credit limits, or may be required to prepay the transaction.
	Dominion and Virginia Power maintain a provision for credit losses based on factors surrounding the credit risk of their customers, historical trends and other information. Management believes, based on credit policies and the December 31, 2013 provision for credit losses, that it is unlikely that a material adverse effect on financial position, results of operations or cash flows would occur as a result of counterparty nonperformance.
	GENERAL
	DOMINION
	As a diversified energy company, Dominion transacts primarily with major companies in the energy industry and with commercial and residential energy consumers. These transactions principally occur in the Northeast, mid-Atlantic and Midwest regions of the U.S. Dominion does not believe that this geographic concentration contributes significantly to its overall exposure to credit risk. In addition, as a result of its large and diverse customer base, Dominion is not exposed to a significant concentration of credit risk for receivables arising from electric and gas utility operations.
	Dominion's exposure to credit risk is concentrated primarily within its energy marketing and price risk management activities, as Dominion transacts with a smaller, less diverse group of counterparties and transactions may involve large notional volumes and potentially volatile commodity prices. Energy marketing and price risk management activities include trading of energy-related commodities, marketing of merchant generation output, structured transactions and the use of financial contracts for enterprise-wide hedging purposes. Gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of any collateral. At December 31, 2013, Dominion's credit exposure totaled $263 million. Of this amount, investment grade counterparties, including those internally rated, represented 63%. No counterparty exposure exceeded 6% of Dominion's total exposure.
	VIRGINIA POWER
	Virginia Power sells electricity and provides distribution and transmission services to customers in Virginia and northeastern North Carolina. Management believes that this geographic concentration risk is mitigated by the diversity of Virginia Power's customer base, which includes residential, commercial and industrial customers, as well as rural electric cooperatives and municipalities. Credit risk associated with trade accounts receivable from energy consumers is limited due to the large number of customers. Virginia Power's exposure to potential concentrations of credit risk results primarily from sales to wholesale customers. Virginia Power's gross credit exposure for each counterparty is calculated as outstanding receivables plus any unrealized on- or off-balance sheet exposure, taking into account contractual netting rights. Gross credit exposure is calculated prior to the application of collateral. At December 31, 2013, Virginia Power's exposure to potential concentrations of credit risk was not considered material.
	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 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 December 31, 2013 and 2012, Dominion would have been required to post an additional $146 million and $110 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 posted $76 million in collateral at December 31, 2013 and $4 million in collateral at December 31, 2012, 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 December 31, 2013 and 2012 was $169 million and $163 million, respectively, which does not include the impact of any offsetting asset positions. Credit-related contingent provisions for Virginia Power were not material as of December 31, 2013 and 2012. See Note 7 for further information about derivative instruments.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related-Party Transactions	'
	RELATED-PARTY TRANSACTIONS
	Virginia Power engages in related-party transactions primarily with other Dominion subsidiaries (affiliates). Virginia Power's receivable and payable balances with affiliates are settled based on contractual terms or on a monthly basis, depending on the nature of the underlying transactions. Virginia Power is included in Dominion's consolidated federal income tax return and participates in certain Dominion benefit plans. A discussion of significant related-party transactions follows.
	Transactions with Affiliates
	Virginia Power transacts with affiliates for certain quantities of natural gas and other commodities in the ordinary course of business. Virginia Power also enters into certain commodity derivative contracts with affiliates. Virginia Power uses these contracts, which are principally comprised of commodity swaps, to manage commodity price risks associated with purchases of natural gas.
	As of December 31, 2013 and 2012, Virginia Power's derivative liabilities with affiliates were not material.
	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 significant transactions with DRS and other affiliates:
	Year Ended December 31,	2013		2012		2011
	(millions)
	Commodity purchases from affiliates	$	417	$	368	$	376
	Services provided by affiliates	415		399		393
	Services provided to affiliates	21		19		21
	In the fourth quarter of 2011, a subsidiary of Virginia Power purchased nuclear fuel-related inventory from an affiliate for $39 million for future use at its nuclear generation stations.
	Virginia Power has borrowed funds from Dominion under short-term borrowing arrangements. There were $97 million and $243 million in short-term demand note borrowings from Dominion as of December 31, 2013 and 2012, respectively. Virginia Power's outstanding borrowings, net of repayments, under the Dominion money pool for its nonregulated subsidiaries totaled $192 million as of December 31, 2012. There were no borrowings as of December 31, 2013. Interest charges related to Virginia Power's borrowings from Dominion were immaterial for the years ended December 31, 2013, 2012 and 2011.
	There were no issuances of Virginia Power's common stock to Dominion in 2013, 2012 or 2011.

Operating_Segments

Operating Segments	12 Months Ended
	Dec. 31, 2013
Segment Reporting Information, Revenue for Reportable Segment [Abstract]	'
Operating Segments	'
	OPERATING SEGMENTS
	Dominion and Virginia Power are organized primarily on the basis of products and services sold in the U.S. A description of the operations included in the Companies' primary operating segments is as follows:
	Primary Operating	Description of Operations	Dominion	Virginia
	Segment			Power
	DVP	Regulated electric distribution	X	X
		Regulated electric transmission	X	X
	Dominion Generation	Regulated electric fleet	X	X
		Merchant electric fleet	X
		Nonregulated retail energy marketing (electric and gas)(1)	X
	Dominion Energy	Gas transmission and storage	X
		Gas distribution and storage	X
		LNG services	X
		Producer services	X
	-1	As a result of Dominion's decision to realign its business units effective for 2013 year-end reporting, nonregulated retail energy marketing operations were moved from DVP to the Dominion Generation segment.
	In addition to the operating segments above, the Companies also report a Corporate and Other segment.
	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 allocating resources among the segments.
	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, which are discussed in Note 3. 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 allocating resources among the segments.
	In the second quarter of 2013, Dominion commenced a restructuring of its producer services business, which aggregates natural gas supply, engages in natural gas trading and marketing activities and natural gas supply management and provides price risk management services to Dominion affiliates. The restructuring resulted in the termination of natural gas trading and certain energy marketing activities. As a result, the earnings impact from natural gas trading and certain energy marketing activities has been included in the Corporate and Other Segment of Dominion.
	DOMINION
	In 2013, Dominion reported after-tax net expense of $452 million in the Corporate and Other segment, with $184 million of these net expenses attributable to specific items related to its operating segments.
	The net expenses for specific items in 2013 primarily related to the impact of the following items:
	•	A $135 million ($92 million after-tax) net loss from discontinued operations of Brayton Point and Kincaid, including debt extinguishment of $64 million ($38 million after-tax) related to the sale, impairment charges of $48 million ($28 million after-tax), a $17 million ($18 million after-tax) loss on the sale which includes a $16 million write-off of goodwill, and a $6 million ($8 million after-tax) loss from operations, attributable to Dominion Generation; and
	•	A $182 million ($109 million after-tax) net loss, including a $55 million ($33 million after-tax) impairment charge related to certain natural gas infrastructure assets and a $127 million ($76 million after-tax) loss related to the producer services business discussed above, attributable to Dominion Energy; partially offset by
	•	An $81 million ($49 million after-tax) net gain on investments held in nuclear decommissioning trust funds, attributable to Dominion Generation.
	In 2012, Dominion reported after-tax net expense of $1.7 billion in the Corporate and Other segment, with $1.5 billion of these net expenses attributable to specific items related to its operating segments.
	The net expenses for specific items in 2012 primarily related to the impact of the following items:
	•	A $1.7 billion ($1.1 billion after-tax) net loss from discontinued operations, including impairment charges, of Brayton Point and Kincaid, which were sold in 2013, attributable to Dominion Generation;
	•	A $467 million ($303 million after-tax) net loss, including impairment charges, primarily resulting from management's decision to cease operations and begin decommissioning Kewaunee in 2013, attributable to Dominion Generation;
	•	An $87 million ($53 million after-tax) charge reflecting restoration costs associated with damage caused by severe storms, attributable to DVP; and
	•	A $49 million ($22 million after-tax) loss from discontinued operations of State Line and Salem Harbor which were sold in 2012, attributable to Dominion Generation.
	In 2011, Dominion reported after-tax net expense of $607 million for specific items in the Corporate and Other segment, with $364 million of these net expenses attributable to specific items related to its operating segments.
	The net expenses for specific items in 2011 primarily related to the impact of the following items:
	•	A $228 million ($139 million after-tax) charge reflecting plant balances that are not expected to be recovered in future periods due to the anticipated retirement of certain utility coal-fired generating units, attributable to Dominion Generation;
	•	A $96 million ($59 million after-tax) charge reflecting restoration costs associated with damage caused by Hurricane Irene, primarily attributable to DVP;
	•	A $66 million ($39 million after-tax) loss from the operations of Kewaunee, attributable to Dominion Generation;
	•	A $57 million ($33 million after-tax) net loss from discontinued operations of Brayton Point and Kincaid, which were sold in 2013, attributable to Dominion Generation;
	•	A $43 million ($26 million after-tax) charge related to the impairment of SO2 emissions allowances not expected to be consumed due to CSAPR, attributable to Dominion Generation; and
	•	A $34 million ($25 million after-tax) loss from discontinued operations of State Line and Salem Harbor which were sold in 2012, attributable to Dominion Generation.
	The following table presents segment information pertaining to Dominion's operations:
	Year Ended December 31,	DVP(1)			Dominion			Dominion			Corporate and			Adjustments &			Consolidated
					Generation(1)(2)			Energy			Other(2)			Eliminations(1)			Total
	(millions)
	2013
	Total revenue from external customers	$	1,825		$	8,445		$	1,783		$	3		$	1,064		$	13,120
	Intersegment revenue	9			68			1,063			609			(1,749		)	—
	Total operating revenue	1,834			8,513			2,846			612			(685		)	13,120
	Depreciation, depletion and amortization	427			518			228			35			—			1,208
	Equity in earnings of equity method investees	—			(14		)	21			7			—			14
	Interest income	—			66			12			42			(66		)	54
	Interest and related charges	175			220			26			522			(66		)	877
	Income taxes	287			483			409			(287		)	—			892
	Loss from discontinued operations, net of tax	—			—			—			(92		)	—			(92		)
	Net income (loss) attributable to Dominion	475			1,031			643			(452		)	—			1,697
	Investment in equity method investees	—			280			615			21			—			916
	Capital expenditures	1,361			1,605			1,043			95			—			4,104
	Total assets (billions)	11.9			22			12.1			8.5			(4.4		)	50.1
	2012
	Total revenue from external customers	$	1,846		$	8,170		$	1,813		$	155		$	851		$	12,835
	Intersegment revenue	9			104			930			608			(1,651		)	—
	Total operating revenue	1,855			8,274			2,743			763			(800		)	12,835
	Depreciation, depletion and amortization	392			483			216			36			—			1,127
	Equity in earnings of equity method investees	—			3			23			(1		)	—			25
	Interest income	1			65			30			71			(106		)	61
Interest and related charges	187			177			47			511			(106		)	816
Income taxes	278			576			352			(395		)	—			811
Loss from discontinued operations, net of tax	—			—			—			(1,125		)	—			(1,125		)
Net income (loss) attributable to Dominion	439			1,021			551			(1,709		)	—			302
Investment in equity method investees	—			414			141			3			—			558
Capital expenditures	1,158			1,615			1,350			22			—			4,145
Total assets (billions)	11.5			21.8			11.2			12.6			(10.3		)	46.8
2011
Total revenue from external customers	$	1,791		$	8,759		$	2,044		$	56		$	1,115		$	13,765
Intersegment revenue	63			123			1,077			595			(1,858		)	—
Total operating revenue	1,854			8,882			3,121			651			(743		)	13,765
Depreciation, depletion and amortization	369			413			207			29			—			1,018
Equity in earnings of equity method investees	—			3			23			9			—			35
Interest income	10			65			27			71			(106		)	67
Interest and related charges	183			148			57			514			(106		)	796
Income taxes	264			655			323			(464		)	—			778
Loss from discontinued operations, net of tax	—			—			—			(58		)	—			(58		)
Net income (loss) attributable to Dominion	416			1,078			521			(607		)	—			1,408
Capital expenditures	1,091			1,593			907			61			—			3,652
(1) Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.
(2) Segment information for 2012 and 2011 has been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
At December 31, 2013, 2012, and 2011, none of Dominion's long-lived assets and no significant percentage of its operating revenues were associated with international operations.
VIRGINIA POWER
The majority of Virginia Power's revenue is provided through tariff rates. Generally, such revenue is allocated for management reporting based on an unbundled rate methodology among Virginia Power's DVP and Dominion Generation segments.
In 2013, Virginia Power reported after-tax net expenses of $47 million for specific items attributable to its operating segments in the Corporate and Other segment.
The net expenses for specific items in 2013 primarily related to the impact of the following:
•	A $40 million ($28 million after-tax) charge in connection with the 2013 Biennial Review Order, attributable to Dominion Generation.
In 2012, Virginia Power reported after-tax net expenses of $51 million for specific items attributable to its operating segments in the Corporate and Other segment.
The net expenses for specific items in 2012 primarily related to the impact of the following:
•	An $87 million ($53 million after-tax) charge reflecting restoration costs associated with damage caused severe storms, attributable to DVP.
In 2011, Virginia Power reported after-tax net expenses of $268 million for specific items attributable to its operating segments in the Corporate and Other segment.
The net expenses for specific items in 2011 primarily related to the impact of the following:
•	A $228 million ($139 million after-tax) charge reflecting plant balances that are not expected to be recovered in future periods due to the anticipated retirement of certain coal-fired generating units, attributable to Dominion Generation;
•	A $96 million ($59 million after-tax) charge reflecting restoration costs associated with damage caused by Hurricane Irene, primarily attributable to DVP; and
•	A $43 million ($26 million after-tax) charge related to the impairment of SO2 emissions allowances not expected to be consumed due to CSAPR, attributable to Dominion Generation.
The following table presents segment information pertaining to Virginia Power's operations:
Year Ended December 31,	DVP			Dominion			Corporate and			Adjustments &			Consolidated
				Generation			Other			Eliminations			Total
(millions)
2013
Operating revenue	$	1,826		$	5,475		$	(6	)	$	—		$	7,295
Depreciation and amortization	427			425			1			—			853
Interest income	—			6			—			—			6
Interest and related charges	175			192			2			—			369
Income taxes	286			399			(26		)	—			659
Net income (loss)	483			702			(47		)	—			1,138
Capital expenditures	1,360			1,173			—			—			2,533
Total assets (billions)	12			15.1			—			(0.1		)	27
2012
Operating revenue	$	1,847		$	5,379		$	—		$	—		$	7,226
Depreciation and amortization	392			390			—			—			782
Interest income	1			7			—			—			8
Interest and related charges	186			199			—			—			385
Income taxes	277			403			(27		)	—			653
Net income (loss)	448			653			(51		)	—			1,050
Capital expenditures	1,142			1,146			—			—			2,288
Total assets (billions)	11.4			14.8			—			(1.4		)	24.8
2011
Operating revenue	$	1,793		$	5,546		$	(93	)	$	—		$	7,246
Depreciation and amortization	368			350			—			—			718
Interest income	10			8			—			—			18
Interest and related charges	182			199			(50		)	—			331
Income taxes	265			447			(172		)	—			540
Net income (loss)	426			664			(268		)	—			822
Capital expenditures	1,081			1,009			—			—			2,090

Quarterly_Financial_and_Common

Quarterly Financial and Common Stock Data (Unaudited)	12 Months Ended
	Dec. 31, 2013
Selected Quarterly Financial Information [Abstract]	'
Quarterly Financial and Common Stock Data (Unaudited)	'
	QUARTERLY FINANCIAL AND COMMON STOCK DATA (UNAUDITED)
	A summary of Dominion's and Virginia Power's quarterly results of operations for the years ended December 31, 2013 and 2012 follows. Amounts reflect all adjustments necessary in the opinion of management for a fair statement of the results for the interim periods. Results for interim periods may fluctuate as a result of weather conditions, changes in rates and other factors.
	DOMINION
		First			Second			Third			Fourth			Full Year
		Quarter			Quarter			Quarter			Quarter (2)
	(millions, except per share amounts)
	2013
	Operating revenue	$	3,523		$	2,980		$	3,432		$	3,185		$	13,120
	Income from operations	930			548			1,034			804			3,316
	Net income including noncontrolling interests	502			208			575			435			1,720
	Income from continuing operations(1)	494			272			592			431			1,789
	Income (loss) from discontinued operations(1)	1			(70		)	(23		)	—			(92		)
	Net income attributable to Dominion	495			202			569			431			1,697
	Basic EPS:
	Income from continuing operations(1)	0.86			0.47			1.02			0.74			3.09
	Income (loss) from discontinued operations(1)	—			(0.12		)	(0.04		)	—			(0.16		)
	Net income attributable to Dominion	0.86			0.35			0.98			0.74			2.93
	Diluted EPS:
	Income from continuing operations(1)	0.86			0.47			1.02			0.74			3.09
	Income (loss) from discontinued operations(1)	—			(0.12		)	(0.04		)	—			(0.16		)
	Net income attributable to Dominion	0.86			0.35			0.98			0.74			2.93
	Dividends declared per share	0.5625			0.5625			0.5625			0.5625			2.25
	Common stock prices (intraday high-low)	$58.25  -			$61.85  -			$64.04 - 55.51			$67.97  -			$67.97  -
		51.92			53.79						61.36			51.92
		First			Second			Third			Fourth			Full Year
		Quarter			Quarter			Quarter			Quarter
	2012
	Operating revenue	$	3,397		$	3,005		$	3,332		$	3,101		$	12,835
	Income from operations	918			628			551			761			2,858
	Net income (loss) including noncontrolling interests	501			265			215			(652		)	329
	Income from continuing operations(1)	504			290			261			372			1,427
	Income (loss) from discontinued operations(1)	(10		)	(32		)	(52		)	(1,031		)	(1,125		)
	Net income attributable to Dominion	494			258			209			(659		)	302
	Basic EPS:
	Income from continuing operations(1)	0.88			0.51			0.45			0.65			2.49
	Loss from discontinued operations(1)	(0.02		)	(0.06		)	(0.09		)	(1.80		)	(1.96		)
	Net income (loss) attributable to Dominion	0.86			0.45			0.36			(1.15		)	0.53
	Diluted EPS:
	Income from continuing operations(1)	0.88			0.51			0.45			0.64			2.49
	Loss from discontinued operations(1)	(0.02		)	(0.06		)	(0.09		)	(1.79		)	(1.96		)
	Net income (loss) attributable to Dominion	0.86			0.45			0.36			(1.15		)	0.53
	Dividends declared per share	0.5275			0.5275			0.5275			0.5275			2.11
	Common stock prices (intraday high-low)	$53.68  -			$54.69  -			$55.62 -			$53.89  -			$55.62  -
		48.87			49.87			52.15			48.94			48.87
	-1	Amounts attributable to Dominion's common shareholders.
	-2	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.
	Dominion's 2013 results include the impact of the following significant items:
	•	Second quarter results include a $70 million after-tax net loss from discontinued operations of Brayton Point and Kincaid; and a $57 million after-tax net loss, including a $33 million after-tax impairment charge related to certain natural gas infrastructure assets and a $24 million after-tax loss related to the producer services business.
	Dominion's 2012 results include the impact of the following significant items:
	•	Fourth quarter results include a $1.0 billion after-tax impairment charge to write down Brayton Point’s and Kincaid's long-lived assets to their estimated fair value.
	•	Third quarter results include a $281 million after-tax net loss, including impairment charges, primarily resulting from management's decision to cease operations and begin decommissioning Kewaunee in 2013.
	VIRGINIA POWER
	Virginia Power's quarterly results of operations were as follows:
		First			Second			Third			Fourth			Year
		Quarter			Quarter			Quarter			Quarter
	(millions)
	2013
	Operating revenue	$	1,781		$	1,710		$	2,059		$	1,745		$	7,295
	Income from operations	530			463			679			408			2,080
	Net income	287			265			387			199			1,138
	Balance available for common stock	283			261			383			194			1,121
	2012
	Operating revenue	$	1,754		$	1,756		$	2,086		$	1,630		$	7,226
Income from operations	468			361			746			417			1,992
Net income	243			172			415			220			1,050
Balance available for common stock	239			168			411			216			1,034
Virginia Power's 2013 results include the impact of the following significant item:
•	Fourth quarter results include a $28 million after-tax charge resulting from impacts of the 2013 Biennial Review Order.
Virginia Power's 2012 results include the impact of the following significant item:
•	Second quarter results include a $42 million after-tax charge reflecting restoration costs associated with damage caused by late June summer storms.

Significant_Accounting_Policie1

Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Operating Revenue	'
	Operating Revenue
	Operating revenue is recorded on the basis of services rendered, commodities delivered or contracts settled and includes amounts yet to be billed to customers. The Companies collect sales, consumption and consumer utility taxes; however, these amounts are excluded from revenue. Dominion's customer receivables at December 31, 2013 and 2012 included $555 million and $411 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity and natural gas delivered but not yet billed to its utility customers. Virginia Power's customer receivables at December 31, 2013 and 2012 included $395 million and $348 million, respectively, of accrued unbilled revenue based on estimated amounts of electricity delivered but not yet billed to its customers.
	The primary types of sales and service activities reported as operating revenue for Dominion are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales, and federally-regulated wholesale electric sales and electric transmission services;
	•	Nonregulated electric sales consist primarily of sales of electricity at market-based rates and contracted fixed rates, and associated derivative activity;
	•	Regulated gas sales consist primarily of state-regulated retail natural gas sales and related distribution services;
	•	Nonregulated gas sales consist primarily of sales of natural gas production at market-based rates and contracted fixed prices, sales of gas purchased from third parties, gas trading and marketing revenue and associated derivative activity;
	•	Gas transportation and storage consists primarily of regulated sales of gathering, transmission, distribution and storage services and associated derivative activity. Also included are regulated gas distribution charges to retail distribution service customers opting for alternate suppliers; and
	•	Other revenue consists primarily of sales of NGL production and condensate, extracted products and associated derivative activity. Other revenue also includes miscellaneous service revenue from electric and gas distribution operations, and gas processing and handling revenue.
	The primary types of sales and service activities reported as operating revenue for Virginia Power are as follows:
	•	Regulated electric sales consist primarily of state-regulated retail electric sales and federally-regulated wholesale electric sales and electric transmission services; and
	•	Other revenue consists primarily of miscellaneous service revenue from electric distribution operations and miscellaneous revenue from generation operations, including sales of capacity and other commodities.
Electric Fuel Purchased Energy and Purchased Gas-Deferred Costs	'
	Electric Fuel, Purchased Energy and Purchased Gas-Deferred Costs
	Where permitted by regulatory authorities, the differences between Virginia Power's actual electric fuel and purchased energy expenses and Dominion's purchased gas expenses and the related levels of recovery for these expenses in current rates are deferred and matched against recoveries in future periods. The deferral of costs in excess of current period fuel rate recovery is recognized as a regulatory asset, while rate recovery in excess of current period fuel expenses is recognized as a regulatory liability.
	Of the cost of fuel used in electric generation and energy purchases to serve utility customers, approximately 84% is currently subject to deferred fuel accounting, while substantially all of the remaining amount is subject to recovery through similar mechanisms.
Income Taxes	'
	Income Taxes
	A consolidated federal income tax return is filed for Dominion and its subsidiaries, including Virginia Power. In addition, where applicable, combined income tax returns for Dominion and its subsidiaries are filed in various states; otherwise, separate state income tax returns are filed. Virginia Power participates in an intercompany tax sharing agreement with Dominion and its subsidiaries, and its current income taxes are based on its taxable income or loss, determined on a separate company basis.
	Accounting for income taxes involves an asset and liability approach. Deferred income tax assets and liabilities are provided, representing future effects on income taxes for temporary differences between the bases of assets and liabilities for financial reporting and tax purposes. Dominion and Virginia Power establish a valuation allowance when it is more-likely-than-not that all, or a portion, of a deferred tax asset will not be realized. Where the treatment of temporary differences is different for rate-regulated operations, a regulatory asset is recognized if it is probable that future revenues will be provided for the payment of deferred tax liabilities.
	Dominion and Virginia Power recognize positions taken, or expected to be taken, in income tax returns that are more-likely-than-not to be realized, assuming that the position will be examined by tax authorities with full knowledge of all relevant information.
	If it is not more-likely-than-not that a tax position, or some portion thereof, will be sustained, the related tax benefits are not recognized in the financial statements. Unrecognized tax benefits may result in an increase in income taxes payable, a reduction of income tax refunds receivable or changes in deferred taxes. Also, when uncertainty about the deductibility of an amount is limited to the timing of such deductibility, the increase in income taxes payable (or reduction in tax refunds receivable) is accompanied by a decrease in deferred tax liabilities. Except when such amounts are presented net with amounts receivable from or amounts prepaid to tax authorities, noncurrent income taxes payable related to unrecognized tax benefits are classified in other deferred credits and other liabilities on the consolidated balance sheets and current payables are included in accrued interest, payroll and taxes on the consolidated balance sheets.
	Dominion and Virginia Power recognize changes in estimated interest payable on net underpayments of income taxes in interest expense. Changes in interest receivable related to net overpayments of income taxes and estimated penalties that may result from the settlement of some uncertain tax positions are recognized in other income. In its Consolidated Statements of Income for 2013, Dominion recognized interest income of $3 million and interest expense of $10 million and no penalties. In 2012, Dominion recognized interest income of $8 million and interest expense of $3 million and a reduction in penalties of less than $1 million. In 2011, Dominion recognized interest income of $12 million and interest expense of $7 million and a reduction in penalties of less than $1 million. Dominion had accrued interest receivable of $5 million, interest payable of $15 million and penalties payable of less than $1 million at December 31, 2013 and interest receivable of $5 million, interest payable of $10 million and penalties payable of less than $1 million at December 31, 2012.
	Virginia Power's interest and penalties were immaterial in 2013 and 2012. In 2011, Virginia Power recognized interest income of $12 million, and penalties were immaterial.
	At December 31, 2013, Virginia Power's Consolidated Balance Sheet included $3 million of state income taxes receivable, $22 million of federal and state income taxes payable, $12 million of noncurrent state income taxes receivable and $28 million of noncurrent federal and state income taxes payable.
	At December 31, 2012, Virginia Power's Consolidated Balance Sheet included $10 million of federal income taxes payable and $36 million of noncurrent federal and state income taxes payable.
	Investment tax credits are recognized by nonregulated operations in the year qualifying property is placed in service. For regulated operations, investment tax credits are deferred and amortized over the service lives of the properties giving rise to the credits. Production tax credits are recognized as energy is generated and sold.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	Current banking arrangements generally do not require checks to be funded until they are presented for payment. At December 31, 2013 and 2012, Dominion's accounts payable included $38 million and $53 million, respectively, of checks outstanding but not yet presented for payment. At December 31, 2013 and 2012, Virginia Power's accounts payable included $21 million and $30 million, respectively, of checks outstanding but not yet presented for payment. For purposes of the Consolidated Statements of Cash Flows, cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with an original maturity of three months or less.
Derivative Instruments	'
	Derivative Instruments
	Dominion and Virginia Power use derivative instruments such as futures, swaps, forwards, options and FTRs to manage the commodity, currency exchange and financial market risks of their business operations.
	All derivatives, other than those for which an exception applies, are reported in the Consolidated Balance Sheets at fair value. Derivative contracts representing unrealized gain positions and purchased options are reported as derivative assets. Derivative contracts representing unrealized losses and options sold are reported as derivative liabilities. One of the exceptions to fair value accounting, normal purchases and normal sales, may be elected when the contract satisfies certain criteria, including a requirement that physical delivery of the underlying commodity is probable. Expenses and revenues resulting from deliveries under normal purchase contracts and normal sales contracts, respectively, are included in earnings at the time of contract performance.
	Dominion and Virginia Power do not offset amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral against amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. Dominion had margin assets of $620 million and $212 million associated with cash collateral at December 31, 2013 and 2012, respectively. Dominion had margin liabilities of $2 million and $4 million associated with cash collateral at December 31, 2013 and 2012, respectively. Virginia Power had margin assets of $11 million and $18 million associated with cash collateral at December 31, 2013 and 2012, respectively. Virginia Power's margin liabilities associated with cash collateral were not material at December 31, 2013 and 2012. See Note 7 for further information about offsetting derivatives.
	To manage price risk, Dominion and Virginia Power hold certain derivative instruments that are not held for trading purposes and are not designated as hedges for accounting purposes. However, to the extent the Companies do not hold offsetting positions for such derivatives, they believe these instruments represent economic hedges that mitigate their exposure to fluctuations in commodity prices, interest rates and foreign exchange rates. As part of Dominion's strategy to market energy and manage related risks, it also manages a portfolio of commodity-based financial derivative instruments held for trading purposes. Dominion uses established policies and procedures to manage the risks associated with price fluctuations in these energy commodities and uses various derivative instruments to reduce risk by creating offsetting market positions.
	Statement of Income Presentation:
	•	Derivatives Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue on a net basis.
	•	Derivatives Not Held for Trading Purposes: All income statement activity, including amounts realized upon settlement, is presented in operating revenue, operating expenses or interest and related charges based on the nature of the underlying risk.
	In Virginia Power's generation operations, changes in the fair value of derivative instruments result in the recognition of regulatory assets or regulatory liabilities for jurisdictions subject to cost-based rate regulation. Realized gains or losses on the derivative instruments are generally recognized when the related transactions impact earnings.
	DERIVATIVE INSTRUMENTS DESIGNATED AS HEDGING INSTRUMENTS
	Dominion and Virginia Power designate a portion of their derivative instruments as either cash flow or fair value hedges for accounting purposes. For all derivatives designated as hedges, Dominion and Virginia Power formally document the relationship between the hedging instrument and the hedged item, as well as the risk management objective and the strategy for using the hedging instrument. The Companies assess whether the hedging relationship between the derivative and the hedged item is highly effective at offsetting changes in cash flows or fair values both at the inception of the hedging relationship and on an ongoing basis. Any change in the fair value of the derivative that is not effective at offsetting changes in the cash flows or fair values of the hedged item is recognized currently in earnings. Also, the Companies may elect to exclude certain gains or losses on hedging instruments from the assessment of hedge effectiveness, such as gains or losses attributable to changes in the time value of options or changes in the difference between spot prices and forward prices, thus requiring that such changes be recorded currently in earnings. Hedge accounting is discontinued prospectively for derivatives that cease to be highly effective hedges. For derivative instruments that are accounted for as fair value hedges or cash flow hedges, the cash flows from the derivatives and from the related hedged items are classified in operating cash flows.
	Cash Flow Hedges-A majority of Dominion's and Virginia Power's hedge strategies represents cash flow hedges of the variable price risk associated with the purchase and sale of electricity, natural gas and other energy-related products. The Companies also use foreign currency contracts to hedge the variability in foreign exchange rates and interest rate swaps to hedge their exposure to variable interest rates on long-term debt. For transactions in which Dominion and Virginia Power are hedging the variability of cash flows, changes in the fair value of the derivatives are reported in AOCI, to the extent they are effective at offsetting changes in the hedged item. Any derivative gains or losses reported in AOCI are reclassified to earnings when the forecasted item is included in earnings, or earlier, if it becomes probable that the forecasted transaction will not occur. For cash flow hedge transactions, hedge accounting is discontinued if the occurrence of the forecasted transaction is no longer probable.
	Fair Value Hedges-Dominion also uses fair value hedges to mitigate the fixed price exposure inherent in certain firm commodity commitments and commodity inventory. In addition, Dominion and Virginia Power have designated interest rate swaps as fair value hedges on certain fixed rate long-term debt to manage interest rate exposure. For fair value hedge transactions, changes in the fair value of the derivative are generally offset currently in earnings by the recognition of changes in the hedged item's fair value. Derivative gains and losses from the hedged item are reclassified to earnings when the hedged item is included in earnings, or earlier, if the hedged item no longer qualifies for hedge accounting. Hedge accounting is discontinued if the hedged item no longer qualifies for hedge accounting.
	See Note 6 for further information about fair value measurements and associated valuation methods for derivatives. See Note 7 for further information on derivatives.
Property, Plant and Equipment	'
	Property, Plant and Equipment
	Property, plant and equipment is recorded at lower of original cost or fair value, if impaired. Capitalized costs include labor, materials and other direct and indirect costs such as asset retirement costs, capitalized interest and, for certain operations subject to cost-of-service rate regulation, AFUDC and overhead costs. The cost of repairs and maintenance, including minor additions and replacements, is generally charged to expense as it is incurred.
	In 2013, 2012 and 2011, Dominion capitalized interest costs and AFUDC to property, plant and equipment of $66 million, $91 million and $85 million, respectively. In 2013, 2012 and 2011, Virginia Power capitalized AFUDC to property, plant and equipment of $33 million, $31 million and $31 million, respectively. Under Virginia law, certain Virginia jurisdictional projects qualify for current recovery of AFUDC through rate adjustment clauses. AFUDC on these projects is calculated and recorded as a regulatory asset and is not capitalized to property, plant and equipment. In 2013, 2012 and 2011, Virginia Power recorded $32 million, $37 million and $20 million of AFUDC related to these projects, respectively.
	For property subject to cost-of-service rate regulation, including Virginia Power electric distribution, electric transmission, and generation property and for certain Dominion natural gas property, the undepreciated cost of such property, less salvage value, is generally charged to accumulated depreciation at retirement. Cost of removal collections from utility customers not representing AROs are recorded as regulatory liabilities. For property subject to cost-of-service rate regulation that will be retired or abandoned significantly before the end of its useful life, the net carrying value is reclassified from plant-in-service when it becomes probable it will be retired or abandoned.
	For Dominion and Virginia Power property that is not subject to cost-of-service rate regulation, including nonutility property, cost of removal not associated with AROs is charged to expense as incurred. The Companies also record gains and losses upon retirement based upon the difference between the proceeds received, if any, and the property's net book value at the retirement date.
	Depreciation of property, plant and equipment is computed on the straight-line method based on projected service lives. Dominion's and Virginia Power's average composite depreciation rates on utility property, plant and equipment are as follows:
	Year Ended December 31,	2013	2012	2011
	(percent)
	Dominion
	Generation	2.71	2.62	2.68
	Transmission	2.36	2.17	2.26
	Distribution	3.13	3.17	3.19
	Storage	2.43	2.59	2.64
	Gas gathering and processing	2.39	2.49	2.52
	General and other	3.82	4.55	4.66
	Virginia Power
	Generation	2.71	2.62	2.68
	Transmission	2.28	1.98	2.03
	Distribution	3.33	3.32	3.33
	General and other	3.51	4.32	4.38
	Dominion's nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives:
	Asset	Estimated Useful Lives
	Merchant generation-nuclear	44 years
	Merchant generation-other	15-36 years
	General and other	5-59 years
	Nuclear fuel used in electric generation is amortized over its estimated service life on a units-of-production basis. Dominion and Virginia Power report the amortization of nuclear fuel in electric fuel and other energy-related purchases expense in their Consolidated Statements of Income and in depreciation and amortization in their Consolidated Statements of Cash Flows.
Long-Lived and Intangible Assets	'
	Long-Lived and Intangible Assets
	Dominion and Virginia Power perform an evaluation for impairment whenever events or changes in circumstances indicate that the carrying amount of long-lived assets or intangible assets with finite lives may not be recoverable. A long-lived or intangible asset is written down to fair value if the sum of its expected future undiscounted cash flows is less than its carrying amount. Intangible assets with finite lives are amortized over their estimated useful lives. See Note 6 for a discussion of impairments related to certain long-lived assets and intangible assets with finite lives.
Regulatory Assets and Liabilities	'
	Regulatory Assets and Liabilities
	The accounting for Dominion's regulated gas and Virginia Power's regulated electric operations differs from the accounting for nonregulated operations in that they are required to reflect the effect of rate regulation in their Consolidated Financial Statements. For regulated businesses subject to federal or state cost-of-service rate regulation, regulatory practices that assign costs to accounting periods may differ from accounting methods generally applied by nonregulated companies. When it is probable that regulators will permit the recovery of current costs through future rates charged to customers, these costs that otherwise would be expensed by nonregulated companies are deferred as regulatory assets. Likewise, regulatory liabilities are recognized when it is probable that regulators will require customer refunds through future rates or when revenue is collected from customers for expenditures that have yet to be incurred. Generally, regulatory assets and liabilities are amortized into income over the period authorized by the regulator.
	The Companies evaluate whether or not recovery of their regulatory assets through future rates is probable and make various assumptions in their analyses. The expectations of future recovery are generally based on orders issued by regulatory commissions or historical experience, as well as discussions with applicable regulatory authorities. If recovery of a regulatory asset is determined to be less than probable, it will be written off in the period such assessment is made.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	Dominion and Virginia Power recognize AROs at fair value as incurred or when sufficient information becomes available to
	determine a reasonable estimate of the fair value of future retirement activities to be performed. These amounts are generally capitalized as costs of the related tangible long-lived assets. Since relevant market information is not available, fair value is estimated using discounted cash flow analyses. At least annually, the Companies evaluate the key assumptions underlying their AROs including estimates of the amounts and timing of future cash flows associated with retirement activities. AROs are adjusted when significant changes in these assumptions are identified. Dominion reports accretion of AROs and depreciation on asset retirement costs associated with its natural gas pipeline and storage well assets as an adjustment to the related regulatory liabilities when revenue is recoverable from customers for AROs. Virginia Power reports accretion of AROs and depreciation on asset retirement costs associated with decommissioning its nuclear power stations as an adjustment to the regulatory liability for certain jurisdictions. Accretion of all other AROs and depreciation of all other asset retirement costs is reported in other operations and maintenance expense and depreciation expense in the Consolidated Statements of Income.
Amortization of Debt Issuance Costs	'
	Amortization of Debt Issuance Costs
	Dominion and Virginia Power defer and amortize debt issuance costs and debt premiums or discounts over the expected lives of the respective debt issues, considering maturity dates and, if applicable, redemption rights held by others. As permitted by regulatory authorities, gains or losses resulting from the refinancing of debt allocable to utility operations subject to cost-based rate regulation are deferred and amortized over the lives of the new issuances.
Investments	'
	Investments
	MARKETABLE EQUITY AND DEBT SECURITIES
	Dominion accounts for and classifies investments in marketable equity and debt securities as trading or available-for-sale securities. Virginia Power classifies investments in marketable equity and debt securities as available-for-sale securities.
	•	Trading securities include marketable equity and debt securities held by Dominion in rabbi trusts associated with certain deferred compensation plans. These securities are reported in other investments in the Consolidated Balance Sheets at fair value with net realized and unrealized gains and losses included in other income in the Consolidated Statements of Income.
	•	Available-for-sale securities include all other marketable equity and debt securities, primarily comprised of securities held in the nuclear decommissioning trusts. These investments are reported at fair value in nuclear decommissioning trust funds in the Consolidated Balance Sheets. Net realized and unrealized gains and losses (including any other-than-temporary impairments) on investments held in Virginia Power's nuclear decommissioning trusts are recorded to a regulatory liability for certain jurisdictions subject to cost-based regulation. For all other available-for-sale securities, including those held in Dominion's merchant generation nuclear decommissioning trusts, net realized gains and losses (including any other-than-temporary impairments) are included in other income and unrealized gains and losses are reported as a component of AOCI, after-tax.
	In determining realized gains and losses for marketable equity and debt securities, the cost basis of the security is based on the specific identification method.
	NON-MARKETABLE INVESTMENTS
	Dominion and Virginia Power account for illiquid and privately held securities for which market prices or quotations are not readily available under either the equity or cost method. Non-marketable investments include:
	•	Equity method investments when Dominion and Virginia Power have the ability to exercise significant influence, but not control, over the investee. Dominion's investments are included in investments in equity method affiliates and Virginia Power's investments are included in other investments in their Consolidated Balance Sheets. Dominion and Virginia Power record equity method adjustments in other income in the Consolidated Statements of Income including: their proportionate share of investee income or loss, gains or losses resulting from investee capital transactions, amortization of certain differences between the carrying value and the equity in the net assets of the investee at the date of investment and other adjustments required by the equity method.
	•	Cost method investments when Dominion and Virginia Power do not have the ability to exercise significant influence over the investee. Dominion's and Virginia Power's investments are included in other investments and nuclear decommissioning trust funds.
	OTHER-THAN-TEMPORARY IMPAIRMENT
	Dominion and Virginia Power periodically review their investments to determine whether a decline in fair value should be considered other-than-temporary. If a decline in fair value of any security is determined to be other-than-temporary, the security is written down to its fair value at the end of the reporting period.
	Decommissioning Trust Investments-Special Considerations
	•	The recognition provisions of the FASB's other-than-temporary impairment guidance apply only to debt securities classified as available-for-sale or held-to-maturity, while the presentation and disclosure requirements apply to both debt and equity securities.
	•	Debt Securities- Using information obtained from their nuclear decommissioning trust fixed-income investment managers, Dominion and Virginia Power record in earnings any unrealized loss for a debt security when the manager intends to sell the debt security or it is more-likely-than-not that the manager will have to sell the debt security before recovery of its fair value up to its cost basis. If that is not the case, but the debt security is deemed to have experienced a credit loss, the Companies record the credit loss in earnings and any remaining portion of the unrealized loss in AOCI. Credit losses are evaluated primarily by considering the credit ratings of the issuer, prior instances of non-performance by the issuer and other factors.
	•	Equity securities and other investments- Dominion's and Virginia Power's method of assessing other-than-temporary declines requires demonstrating the ability to hold individual securities for a period of time sufficient to allow for the anticipated recovery in their market value prior to the consideration of the other criteria mentioned above. Since the Companies have limited ability to oversee the day-to-day management of nuclear decommissioning trust fund investments, they do not have the ability to ensure investments are held through an anticipated recovery period. Accordingly, they consider all equity and other securities as well as non-marketable investments held in nuclear decommissioning trusts with market values below their cost bases to be other-than-temporarily impaired.
Inventories	'
	Inventories
	Materials and supplies and fossil fuel inventories are valued primarily using the weighted-average cost method. Stored gas inventory used in East Ohio gas distribution operations is valued using the LIFO method. Under the LIFO method, stored gas inventory was valued at $7 million and $24 million at December 31, 2013 and December 31, 2012, respectively. Based on the average price of gas purchased during 2013 and 2012, the cost of replacing the current portion of stored gas inventory exceeded the amount stated on a LIFO basis by approximately $77 million and $69 million, respectively. Stored gas inventory held by Hope and certain nonregulated gas operations is valued using the weighted-average cost method.
Gas Imbalances	'
	Gas Imbalances
	Natural gas imbalances occur when the physical amount of natural gas delivered from, or received by, a pipeline system or storage facility differs from the contractual amount of natural gas delivered or received. Dominion values these imbalances due to, or from, shippers and operators at an appropriate index price at period end, subject to the terms of its tariff for regulated entities. Imbalances are primarily settled in-kind. Imbalances due to Dominion from other parties are reported in other current assets and imbalances that Dominion owes to other parties are reported in other current liabilities in the Consolidated Balance Sheets.
Goodwill	'
	Goodwill
	Dominion evaluates goodwill for impairment annually as of April 1 and whenever an event occurs or circumstances change in the interim that would more-likely-than-not reduce the fair value of a reporting unit below its carrying amount.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of Depreciation Rates	'
	Dominion's and Virginia Power's average composite depreciation rates on utility property, plant and equipment are as follows:
	Year Ended December 31,	2013	2012	2011
	(percent)
	Dominion
	Generation	2.71	2.62	2.68
	Transmission	2.36	2.17	2.26
	Distribution	3.13	3.17	3.19
	Storage	2.43	2.59	2.64
	Gas gathering and processing	2.39	2.49	2.52
	General and other	3.82	4.55	4.66
	Virginia Power
	Generation	2.71	2.62	2.68
	Transmission	2.28	1.98	2.03
	Distribution	3.33	3.32	3.33
	General and other	3.51	4.32	4.38
Schedule of Estimated Useful Life	'
	Dominion's nonutility property, plant and equipment is depreciated using the straight-line method over the following estimated useful lives:
	Asset	Estimated Useful Lives
	Merchant generation-nuclear	44 years
	Merchant generation-other	15-36 years
	General and other	5-59 years

Dispositions_Tables

Dispositions (Tables)	12 Months Ended
	Dec. 31, 2013
Brayton Point and Kincaid	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement Disclosures	'
	The following table presents selected information regarding the results of operations of Brayton Point and Kincaid, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
	Year Ended December 31,	2013				2012				2011
	(millions)
	Operating revenue	$	304			$	258			$	380
	Loss before income taxes	(135		)	(1)	(1,768		)	(2)	(57		)
	(1) Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013. See Note 17 for more information.
	(2) Includes a long-lived asset impairment charge of $1.6 billion.
State Line and Salem Harbor	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement Disclosures	'
	The following table presents selected information regarding the results of operations of Salem Harbor and State Line, which are reported as discontinued operations in Dominion's Consolidated Statements of Income:
	Year Ended December 31,	2012			2011
	(millions)
	Operating revenue	$	57		$	233
	Loss before income taxes(1)	(49		)	(34		)
	-1	Includes long-lived asset impairment charges of $55 million in 2011.

Operating_Revenue_Tables

Operating Revenue (Tables)	12 Months Ended
	Dec. 31, 2013
Regulated and Unregulated Operating Revenue [Abstract]	'
Operating Revenue, Table	'
	Dominion's and Virginia Power's operating revenue consists of the following:
	Year Ended December 31,	2013		2012		2011
	(millions)
	Dominion
	Electric sales:
	Regulated	$	7,193	$	7,102	$	7,114
	Nonregulated	2,511		2,483		2,721
	Gas sales:
	Regulated	323		250		287
	Nonregulated	930		1,071		1,634
	Gas transportation and storage	1,535		1,401		1,506
	Other	628		528		503
	Total operating revenue	$	13,120	$	12,835	$	13,765
	Virginia Power
	Regulated electric sales	$	7,193	$	7,102	$	7,114
	Other	102		124		132
	Total operating revenue	$	7,295	$	7,226	$	7,246

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income tax expense for continuing operations including noncontrolling interests	'
	Details of income tax expense for continuing operations including noncontrolling interests were as follows:
		Dominion(1)									Virginia Power(2)
	Year Ended December 31,	2013			2012			2011			2013			2012			2011
	(millions)
	Current:
	Federal	$	317		$	43		$	31		$	357		$	70		$	(35	)
	State	110			84			16			62			81			79
	Total current expense	427			127			47			419			151			44
	Deferred:
	Federal	497			645			685			224			482			484
	State	(31		)	40			48			17			21			13
	Total deferred expense	466			685			733			241			503			497
	Amortization of deferred investment tax credits	(1		)	(1		)	(2		)	(1		)	(1		)	(1		)
	Total income tax expense	$	892		$	811		$	778		$	659		$	653		$	540
	-1	In 2012, Dominion’s current federal income tax expense for continuing and discontinued operations includes a $195 million benefit related to a carryback of its 2012 net operating loss. In 2011, Dominion’s deferred federal income tax expense includes the recognition of a $346 million benefit, including $51 million related to discontinued operations, for its 2011 net operating loss expected to be used to reduce taxable income in future years.
	-2	In 2011, Virginia Power’s deferred federal income tax expense includes a $54 million benefit related to a portion of its 2011 net operating loss that is expected to be used in future years. Also, Virginia Power’s current federal income tax expense reflects the amounts of its 2011 net operating losses realized through its participation in a tax sharing agreement with Dominion and its subsidiaries.
Effective income tax	'
	For continuing operations including noncontrolling interests, the statutory U.S. federal income tax rate reconciles to Dominion's and Virginia Power's effective income tax rate as follows:
		Dominion						Virginia Power
	Year Ended December 31,	2013		2012		2011		2013		2012		2011
	U.S. statutory rate	35	%	35	%	35	%	35	%	35	%	35	%
	Increases (reductions) resulting from:
	State taxes, net of federal benefit	2.1		4.2		1.9		3.1		3.9		4.4
	Valuation allowances	(0.1	)	(0.7	)	—		—		—		—
	Investment and production tax credits	(2.4	)	(0.5	)	(0.6	)	(0.2	)	—		—
	AFUDC - equity	(0.6	)	(0.9	)	(0.6	)	(0.8	)	(0.9	)	(0.8	)
	Employee stock ownership plan deduction	(0.6	)	(0.7	)	(0.6	)	—		—		—
	Other, net	(0.4	)	(0.6	)	(0.7	)	(0.4	)	0.3		1.1
	Effective tax rate	33	%	35.8	%	34.4	%	36.7	%	38.3	%	39.7	%
The Companies deferred income taxes components	'
	The Companies' deferred income taxes consist of the following:
		Dominion						Virginia Power
	At December 31,	2013			2012			2013			2012
	(millions)
	Deferred income taxes:
	Total deferred income tax assets	$	2,142		$	2,505		$	462		$	466
	Total deferred income tax liabilities	8,463			7,716			4,498			4,238
	Total net deferred income tax liabilities	$	6,321		$	5,211		$	4,036		$	3,772
	Total deferred income taxes:
	Plant and equipment, primarily depreciation method and basis differences	$	5,383		$	4,601		$	3,628		$	3,394
	Nuclear decommissioning	1,136			994			441			407
	Deferred state income taxes	606			474			285			265
	Federal benefit of deferred state income taxes	(212		)	(166		)	(100		)	(93		)
	Deferred fuel, purchased energy and gas costs	(33		)	3			(50		)	(16		)
	Pension benefits	435			231			(52		)	(17		)
	Other postretirement benefits	(78		)	(171		)	(3		)	(7		)
	Loss and credit carryforwards	(797		)	(656		)	(106		)	(77		)
	Valuation allowances	69			93			—			—
	Partnership basis differences	125			174			—			—
	Other	(313		)	(366		)	(7		)	(84		)
	Total net deferred income tax liabilities	$	6,321		$	5,211		$	4,036		$	3,772
Reconciliation of changes in the Companies unrecognized tax benefits	'
	A reconciliation of changes in the Companies' unrecognized tax benefits follows:
		Dominion									Virginia Power
		2013			2012			2011			2013			2012			2011
	(millions)
	Balance at January 1	$	293		$	347		$	307		$	57		$	114		$	117
	Increases-prior period positions	17			28			127			12			4			22
	Decreases-prior period positions	(99		)	(106		)	(119		)	(42		)	(80		)	(51		)
	Increases-current period positions	30			43			64			14			24			47
	Decreases-current period positions	(5		)	—			(21		)	—			—			(21		)
	Settlements with tax authorities	(2		)	(4		)	—			(2		)	(4		)	—
	Expiration of statutes of limitations	(12		)	(15		)	(11		)	—			(1		)	—
	Balance at December 31	$	222		$	293		$	347		$	39		$	57		$	114
Earliest tax year remaining	'
	For each of the major states in which Dominion operates, the earliest tax year remaining open for examination is as follows:
	State	Earliest
		Open Tax
		Year
	Pennsylvania	2010
	Connecticut	2010
	Massachusetts	2008
	Virginia(1)	2010
	West Virginia	2010
	-1	Virginia is the only state considered major for Virginia Power's operations.
Schedule of Components of Income Tax Expense (Benefit) from Discontinued Operations [Table Text Block]	'
	Details of income tax expense for discontinued operations were as follows:
		Dominion
	Year Ended December 31,	2013		2012		2011
	(millions)
	Current:
	Federal	(274	)	(248	)	(41	)
	State	(41	)	(6	)	(17	)
	Total current benefit	(315	)	(254	)	(58	)
	Deferred:
	Federal	232		(368	)	10
	State	40		(70	)	15
	Total deferred expense (benefit)	272		(438	)	25
	Total income tax benefit	(43	)	(692	)	(33	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
Fair Value, Option, Quantitative Disclosures	'
	The following table presents Dominion's and Virginia Power's quantitative information about Level 3 fair value measurements. The range and weighted average are presented in dollars for market price inputs, years for mean reversion speeds, and percentages for price volatility, price correlations, load shaping, and usage factors.
		Fair Value (millions)			Valuation Techniques	Unobservable Input		Range		Weighted Average(1)
	At December 31, 2013
	Assets:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	14		Discounted Cash Flow	Market Price (per Dth)	(5)	(2) - 5		2
	FTRs (3)	2			Discounted Cash Flow	Market Price (per MWh)	(5)	(1) - 5		—
	Liquids(4)	6			Discounted Cash Flow	Market Price (per Gal)	(5)	3-Jan		1
	Physical and Financial Options:
	Natural Gas(2)	4			Option Model	Market Price (per Dth)	(5)	5-Mar		4
						Price Volatility	(6)	14% - 36%		20	%
						Price Correlation	(7)	(9%) - 100%		36	%
						Mean Reversion	(8)	.01 - 1		0.53
	Full Requirements Contracts:
	Electricity	6			Discounted Cash Flow	Market Price (per MWh)	(5)	10 - 406	(11)	42
						Load Shaping	(9)	0% - 10%		7	%
						Usage Factor	(10)	11% - 29%		16	%
	Total assets	$	32
	Liabilities:
	Physical and Financial Forwards and Futures:
	Natural Gas(2)	$	19		Discounted Cash Flow	Market Price (per Dth)	(5)	(2) - 30		1
	Electricity	1			Discounted Cash Flow	Market Price (per MWh)	(5)	28 - 240	(11)	39
	FTRs(3)	9			Discounted Cash Flow	Market Price (per MWh)	(5)	(1) - 5		1
	Liquids(4)	11			Discounted Cash Flow	Market Price (per Gal)	(5)	3-Jan		1
	Physical and Financial Options:
	Natural Gas(2)	8			Option Model	Market Price (per Dth)	(5)	11-Mar		7
						Price Volatility	(6)	14% - 36%		20	%
						Price Correlation	(7)	(9%) - 100%		36	%
						Mean Reversion	(8)	.01-1		0.53
	Total liabilities	$	48
	-1	Averages weighted by volume.
	-2	Includes basis.
	-3	Information represents Virginia Power's quantitative information about Level 3 fair value measurements.
	-4	Includes NGLs.
	-5	Represents market prices beyond defined terms for Levels 1 and 2.
	-6	Represents volatilities unrepresented in published markets.
	-7	Represents intra-price correlations for which markets do not exist.
	-8	Represents mean-reverting property in price simulation modeling.
	-9	Converts block monthly loads to 24-hour load shapes.
	-10	Represents expected increase (decrease) in sales volumes compared to historical usage.
	-11	The range in market prices is the result of large variability in hourly power prices during peak and off-peak hours.
Fair Value, Option, Qualitative Disclosures Related to Election	'
	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)
	Price Correlation	Buy	Increase (decrease)	Loss (gain)
	Price Correlation	Sell	Increase (decrease)	Gain (loss)
	Load Shaping	Sell(1)	Increase (decrease)	Loss (gain)
	Usage Factor	Sell(2)	Increase (decrease)	Gain (loss)
	Mean Reversion	Buy	Increase (decrease)	Loss (gain)
	Mean Reversion	Sell	Increase (decrease)	Gain (loss)
	-1	Assumes the contract is in a gain position and load increases during peak hours.
	-2	Assumes the contract is in a gain position.
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 December 31, 2013
	Assets:
	Derivatives:
	Commodity	$	3		$	718		$	32		$	753
	Interest rate	—			137			—			137
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	2,417			—			—			2,417
	Other	79			—			—			79
	Non-U.S.:
	Large Cap	13			—			—			13
	Fixed Income:
	Corporate debt instruments	—			345			—			345
	U.S. Treasury securities and agency debentures	415			175			—			590
	State and municipal	—			343			—			343
	Other	—			3			—			3
	Cash equivalents and other	—			103			—			103
	Restricted cash equivalents	—			8			—			8
	Total assets	$	2,927		$	1,832		$	32		$	4,791
	Liabilities:
	Derivatives:
	Commodity	$	3		$	1,051		$	48		$	1,102
	Total liabilities	$	3		$	1,051		$	48		$	1,102
	At December 31, 2012
	Assets:
	Derivatives:
	Commodity	$	12		$	639		$	84		$	735
	Interest rate	—			93			—			93
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	1,973			—			—			1,973
	Other	59			—			—			59
	Non-U.S.:
	Large Cap	12			—			—			12
	Fixed Income:
	Corporate debt instruments	—			325			—			325
	U.S. Treasury securities and agency debentures	391			152			—			543
	State and municipal	—			315			—			315
	Other	—			7			—			7
	Cash equivalents and other	13			67			—			80
	Restricted cash equivalents	—			33			—			33
	Total assets	$	2,460		$	1,631		$	84		$	4,175
	Liabilities:
	Derivatives:
	Commodity	$	8		$	528		$	59		$	595
	Interest rate	—			66			—			66
	Total liabilities	$	8		$	594		$	59		$	661
	-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:
		2013			2012			2011
	(millions)
	Balance at January 1,	$	25		$	(71	)	$	(50	)
	Total realized and unrealized gains (losses):
	Included in earnings	(9		)	(15		)	(77		)
	Included in other comprehensive income (loss)	1			101			14
	Included in regulatory assets/liabilities	(9		)	30			(42		)
	Settlements	(23		)	47			88
	Transfers out of Level 3	(1		)	(67		)	(4		)
	Balance at December 31,	$	(16	)	$	25		$	(71	)
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	$	—		$	42		$	22
Fair Value, Unobservable Inputs, Gain (Loss) Included In Earnings	'
	The following table presents Dominion's gains and losses included in earnings in the Level 3 fair value category:
		Operating			Electric Fuel			Purchased			Total
		Revenue			and Energy			Gas
					Purchases
	(millions)
	Year Ended December 31, 2013
	Total gains (losses) included in earnings	$	11		$	(19	)	$	(1	)	$	(9	)
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	1			—			(1		)	—
	Year Ended December 31, 2012
	Total gains (losses) included in earnings	$	35		$	(50	)	$	—		$	(15	)
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	42			—			—			42
	Year Ended December 31, 2011
	Total gains (losses) included in earnings	$	(32	)	$	(45	)	$	—		$	(77	)
	The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	22			—			—			22
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments	'
	For Dominion's and Virginia Power's financial instruments that are not recorded at fair value, the carrying amounts and fair values are as follows:
	At December 31,	2013						2012
		Carrying			Estimated			Carrying			Estimated
		Amount			Fair Value(1)			Amount			Fair Value(1)
	(millions)
	Dominion
	Long-term debt, including securities due within one year(2)	$	18,396		$	19,887		$	16,841		$	19,898
	Long-term debt, including securities due within one year - VIE(3)	—			—			860			864
	Junior subordinated notes(3)	1,373			1,394			1,373			1,430
	Remarketable subordinated notes(3)	1,080			1,192			—			—
	Subsidiary preferred stock(4)	257			261			257			255
	Virginia Power
	Long-term debt, including securities due within one year(2)	$	8,032		$	8,897		$	6,669		$	8,270
	Preferred stock(4)	257			261			257			255
	-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 discount and premium. At December 31, 2013, and 2012, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of approximately $55 million and $93 million, respectively.
	-3	Carrying amount includes amounts which represent the unamortized discount or premium.
	-4	Includes deferred issuance expenses of $2 million at December 31, 2013 and 2012.
Virginia Electric and Power Company	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'
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 December 31, 2013
	Assets:
	Derivatives:
	Commodity	$	—		$	3		$	2		$	5
	Interest rate	—			48			—			48
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	1,021			—			—			1,021
	Other	36			—			—			36
	Fixed Income:
	Corporate debt instruments	—			191			—			191
	U.S. Treasury securities and agency debentures	146			66			—			212
	State and municipal	—			164			—			164
	Cash equivalents and other	—			31			—			31
	Restricted cash equivalents	—			8			—			8
	Total assets	$	1,203		$	511		$	2		$	1,716
	Liabilities:
	Derivatives:
	Commodity	$	—		$	3		$	9		$	12
	Total Liabilities	$	—		$	3		$	9		$	12
	At December 31, 2012
	Assets:
	Derivatives:
	Commodity	$	—		$	1		$	5		$	6
	Investments(1):
	Equity securities:
	U.S.:
	Large Cap	779			—			—			779
	Other	27			—			—			27
	Fixed Income:
	Corporate debt instruments	—			196			—			196
	U.S. Treasury securities and agency debentures	168			66			—			234
	State and municipal	—			118			—			118
	Other	—			1			—			1
	Cash equivalents and other	7			31			—			38
	Restricted cash equivalents	—			10			—			10
	Total assets	$	981		$	423		$	5		$	1,409
	Liabilities:
	Derivatives:
	Commodity	$	—		$	6		$	3		$	9
	Interest rate	—			25			—			25
	Total Liabilities	$	—		$	31		$	3		$	34
	-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:
		2013			2012			2011
	(millions)
	Balance at January 1,	$	2		$	(28	)	$	14
	Total realized and unrealized gains (losses):
	Included in earnings	(17		)	(50		)	(45		)
	Included in regulatory assets/liabilities	(9		)	30			(42		)
	Settlements	17			50			45
	Balance at December 31,	$	(7	)	$	2		$	(28	)

Derivatives_and_Hedge_Accounti1

Derivatives and Hedge Accounting Activities (Tables)	12 Months Ended
	Dec. 31, 2013
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:
		31-Dec-13									31-Dec-12
		Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	137		$	—		$	137		$	93	$	—	$	93
	Commodity contracts:
	Over-the-counter	240			—			240			290		—		290
	Exchange	506			—			506			416		—		416
	Total derivatives, subject to a master netting or similar arrangement	883			—			883			799		—		799
	Total derivatives, not subject to a master netting or similar arrangement	7			—			7			29		—		29
	Total(1)	$	890		$	—		$	890		$	828	$	—	$	828
	-1	At December 31, 2013, the total derivative asset balance contains $687 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $203 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
					31-Dec-13										31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet										Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	137		$	—		$	—		$	137	$	93	$	19	$	—	$	74
	Commodity contracts:
	Over-the-counter	240			63			—			177		290		97		—		193
	Exchange	506			505			—			1		416		350		4		62
	Total	$	883		$	568		$	—		$	315	$	799	$	466	$	4	$	329
Offsetting Liabilities	'
		31-Dec-13									31-Dec-12
		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)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	66	$	—	$	66
	Commodity contracts:
	Over-the-counter	262			—			262			191		—		191
	Exchange	838			—			838			393		—		393
	Total derivatives, subject to a master netting or similar arrangement	1,100			—			1,100			650		—		650
	Total derivatives, not subject to a master netting or similar arrangement	2			—			2			11		—		11
	Total(1)	$	1,102		$	—		$	1,102		$	661	$	—	$	661
	-1	At December 31, 2013, the total derivative liability balance contains $828 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $274 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.
					31-Dec-13										31-Dec-12
					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)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	—	$	66	$	19	$	—	$	47
	Commodity contracts:
	Over-the-counter	262			63			69			130		191		97		20		74
	Exchange	838			505			333			—		393		350		43		—
	Total	$	1,100		$	568		$	402		$	130	$	650	$	466	$	63	$	121
Volumes of Derivatives	'
	The following table presents the volume of Dominion's derivative activity as of December 31, 2013. 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)	116			19
	Basis(1)	466			281
	Electricity (MWh):
	Fixed price(1)	14,814,767			14,935,144
	FTRs	41,316,345			437,384
	Capacity (MW)	83,050			18,300
	Liquids (gallons)(2)	151,200,000			—
	Interest rate	$	2,050,000,000		$	750,000,000
	-1	Includes options.
	-2	Includes NGLs and oil.
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 December 31, 2013:
		AOCI			Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax			Maximum
		After-Tax						Term
	(millions)
	Commodities:
	Gas	$	(3	)	$	(3	)	28 months
	Electricity	(172		)	(124		)	36 months
	Other	(3		)	(3		)	29 months
	Interest rate	(110		)	(7		)	364 months
	Total	$	(288	)	$	(137	)
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following tables present the fair values of Dominion's derivatives and where they are presented in its Consolidated Balance Sheets:
		Fair Value  -			Fair Value -			Total
		Derivatives			Derivatives			Fair
		under			not under			Value
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	At December 31, 2013
	ASSETS
	Current Assets
	Commodity	$	49		$	522		$	571
	Interest rate	116			—			116
	Total current derivative assets	165			522			687
	Noncurrent Assets
	Commodity	28			154			182
	Interest rate	21			—			21
	Total noncurrent derivative assets(1)	49			154			203
	Total derivative assets	$	214		$	676		$	890
	LIABILITIES
	Current Liabilities
	Commodity	$	267		$	561		$	828
	Total current derivative liabilities	267			561			828
	Noncurrent Liabilities
	Commodity	119			155			274
	Total noncurrent derivative liabilities(2)	119			155			274
	Total derivative liabilities	$	386		$	716		$	1,102
	At December 31, 2012
	ASSETS
	Current Assets
	Commodity	$	103		$	379		$	482
	Interest rate	36			—			36
	Total current derivative assets	139			379			518
	Noncurrent Assets
	Commodity	130			123			253
	Interest rate	57			—			57
	Total noncurrent derivative assets(1)	187			123			310
	Total derivative assets	$	326		$	502		$	828
	LIABILITIES
	Current Liabilities
	Commodity	$	103		$	341		$	444
	Interest rate	66			—			66
	Total current derivative liabilities	169			341			510
	Noncurrent Liabilities
	Commodity	58			93			151
	Total noncurrent derivative liabilities(2)	58			93			151
	Total derivative liabilities	$	227		$	434		$	661
	-1	Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion's Consolidated Balance Sheets.
	-2	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion's Consolidated Balance Sheets.
Derivative Instruments Gain (Loss) by Hedging Relationship by Income Statement Location	'
	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	Amount of			Amount of			Increase
	relationships	Gain (Loss)			Gain (Loss)			(Decrease)
		Recognized			Reclassified			in
		in AOCI on			from AOCI			Derivatives
		Derivatives			to Income			Subject to
		(Effective						Regulatory
		Portion)(1)						Treatment(2)
	(millions)
	Year Ended December 31, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	(58	)
	Purchased gas				(47		)
	Electric fuel and other energy-related purchases				(10		)
	Total commodity	$	(481	)	$	(115	)	$	5
	Interest rate(3)	77			(15		)	81
	Total	$	(404	)	$	(130	)	$	86
	Year Ended December 31, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	188
	Purchased gas				(75		)
	Electric fuel and other energy-related purchases				(17		)
	Total commodity	$	71		$	96		$	10
	Interest rate(3)	(84		)	(2		)	(35		)
	Total	$	(13	)	$	94		$	(25	)
	Year Ended December 31, 2011
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue				$	153
	Purchased gas				(78		)
	Electric fuel and other energy-related purchases				(2		)
	Purchased electric capacity				1
	Total commodity	$	137		$	74		$	(20	)
	Interest rate(3)	(252		)	(8		)	(143		)
	Total	$	(115	)	$	66		$	(163	)
	-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.
Schedule Of Derivatives Not Designated As Hedging Instruments	'
	Derivatives not designated as hedging	Amount of Gain (Loss) Recognized in Income on Derivatives(1)
	instruments
	Year Ended December 31,	2013			2012			2011
	(millions)
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Operating revenue	$	(45	)	$	168		$	111
	Purchased gas	(9		)	(14		)	(35		)
	Electric fuel and other energy-related purchases	(29		)	(40		)	(45		)
	Interest rate(2)	—			17			(5		)
	Total	$	(83	)	$	131		$	26
	-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	Amounts recorded in Dominion's Consolidated Statements of Income are classified in interest and related charges.
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:
		31-Dec-13									31-Dec-12
		Gross Amounts of Recognized Assets			Gross Amounts Offset in the Consolidated Balance Sheet			Net Amounts of Assets Presented in the Consolidated Balance Sheet			Gross Amounts of Recognized Assets		Gross Amounts Offset in the Consolidated Balance Sheet		Net Amounts of Assets Presented in the Consolidated Balance Sheet
	(millions)
	Interest rate contracts:
	Over-the-counter	$	48		$	—		$	48		$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	4			—			4			6		—		6
	Exchange	1			—			1			—		—		—
	Total derivatives, subject to a master netting or similar arrangement	53			—			53			6		—		6
	Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—		—		—
	Total(1)	$	53		$	—		$	53		$	6	$	—	$	6
	-1	At December 31, 2013, the total derivative asset balance contains $53 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $6 million of current assets, which is presented in other current assets in Virginia Power’s Consolidated Balance Sheet.
					31-Dec-13										31-Dec-12
					Gross Amounts Not Offset in the Consolidated Balance Sheet										Gross Amounts Not Offset in the Consolidated Balance Sheet
		Net Amounts of Assets Presented in the Consolidated Balance Sheet			Financial Instruments			Cash Collateral Received			Net Amounts		Net Amounts of Assets Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Received		Net Amounts
	(millions)
	Interest rate contracts:
	Over-the-counter	$	48		$	—		$	—		$	48	$	—	$	—	$	—	$	—
	Commodity contracts:
	Over-the-counter	4			4			—			—		6		3		—		3
	Exchange	1			—			—			1		—		—		—		—
	Total	$	53		$	4		$	—		$	49	$	6	$	3	$	—	$	3
Offsetting Liabilities	'
		31-Dec-13									31-Dec-12
		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)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	25	$	—	$	25
	Commodity contracts:
	Over-the-counter	12			—			12			7		—		7
	Exchange	—			—			—			2		—		2
	Total derivatives, subject to a master netting or similar arrangement	12			—			12			34		—		34
	Total derivatives, not subject to a master netting or similar arrangement	—			—			—			—		—		—
	Total(1)	$	12		$	—		$	12		$	34	$	—	$	34
	-1	At December 31, 2013, the total derivative liability balance contains $12 million of current liabilities, which is presented in current derivative liabilities in Virginia Power’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $33 million of current liabilities, which is presented in current derivative liabilities in Virginia Power’s Consolidated Balance Sheet and $1 million of noncurrent derivative liabilities, which is presented in other deferred credits and other liabilities in Virginia Power’s Consolidated Balance Sheet.
					31-Dec-13										31-Dec-12
					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)
	Interest rate contracts:
	Over-the-counter	$	—		$	—		$	—		$	—	$	25	$	—	$	—	$	25
	Commodity contracts:
	Over-the-counter	12			4			7			1		7		3		—		4
	Exchange	—			—			—			—		2		—		2		—
	Total	$	12		$	4		$	7		$	1	$	34	$	3	$	2	$	29
Volumes of Derivatives	'
	The following table presents the volume of Virginia Power's derivative activity at December 31, 2013. 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	15			—
	Basis	7			—
	Electricity (MWh):
	Fixed price	624,800			—
	FTRs	39,186,609			—
	Capacity (MW)	75,500			18,300
	Interest rate	$	600,000,000		$	—
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following tables present the fair values of Virginia Power's derivatives and where they are presented in its Consolidated Balance Sheets:
		Fair Value  -			Fair Value -			Total
		Derivatives			Derivatives			Fair
		under			not under			Value
		Hedge			Hedge
		Accounting			Accounting
	(millions)
	At December 31, 2013
	ASSETS
	Current Assets
	Commodity	$	2		$	3		$	5
	Interest rate	48						48
	Total current derivative assets(1)	50			3			53
	Total derivative assets	$	50		$	3		$	53
	LIABILITIES
	Current Liabilities
	Commodity	$	1		$	11		$	12
	Total current derivative liabilities	1			11			12
	Total derivative liabilities	$	1		$	11		$	12
	At December 31, 2012
	ASSETS
	Current Assets
	Commodity	$	1		$	5		$	6
	Total current derivative assets(1)	1			5			6
	Total derivative assets	$	1		$	5		$	6
	LIABILITIES
	Current Liabilities
	Commodity	$	5		$	3		$	8
	Interest rate	25			—			25
	Total current derivative liabilities	$	30		$	3		$	33
	Noncurrent Liabilities
	Commodity	1			—			1
	Total noncurrent derivative liabilities(2)	1			—			1
	Total derivative liabilities	$	31		$	3		$	34
	-1	Current derivative assets are presented in other current assets in Virginia Power's Consolidated Balance Sheets.
	-2	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Virginia Power's Consolidated Balance Sheets.
Derivative Instruments Gain (Loss) by Hedging Relationship by Income Statement Location	'
	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	Amount of Gain			Amount of			Increase
	relationships	(Loss)			Gain (Loss)			(Decrease) in
		Recognized in			Reclassified			Derivatives
		AOCI on			from AOCI to			Subject to
		Derivatives			Income			Regulatory
		(Effective						Treatment(2)
		Portion)(1)
	(millions)
	Year Ended December 31, 2013
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	—
	Total commodity	$	—		$	—		$	5
	Interest rate(3)	9			—			81
	Total	$	9		$	—		$	86
	Year Ended December 31, 2012
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	(4	)
	Total commodity	$	(2	)	$	(4	)	$	10
	Interest rate(3)	(6		)	—			(35		)
	Total	$	(8	)	$	(4	)	$	(25	)
	Year Ended December 31, 2011
	Derivative Type and Location of Gains (Losses)
	Commodity:
	Electric fuel and other energy-related purchases				$	(1	)
	Purchased electric capacity				1
	Total commodity	$	(3	)	$	—		$	(20	)
	Interest rate(3)	(6		)	1			(143		)
	Total	$	(9	)	$	1		$	(163	)
	-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	'
	Derivatives not designated as hedging	Amount of Gain (Loss) Recognized
	instruments	in Income on Derivatives(1)
	Year Ended December 31,	2013			2012			2011
	(millions)
	Derivative Type and Location of Gains (Losses)
	Commodity(2)	$	(16	)	$	(50	)	$	(45	)
	Interest rate(3)	—			—			(5		)
	Total	$	(16	)	$	(50	)	$	(50	)
	-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.
	-3	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in interest and related charges.

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share Computation	'
	The following table presents the calculation of Dominion's basic and diluted EPS:
		2013		2012		2011
	(millions, except EPS)
	Net income attributable to Dominion	$	1,697	$	302	$	1,408
	Average shares of common stock outstanding-Basic	578.7		572.9		573.1
	Net effect of dilutive securities(1)	0.8		1		1.5
	Average shares of common stock outstanding-Diluted	579.5		573.9		574.6
	Earnings Per Common Share-Basic	$	2.93	$	0.53	$	2.46
	Earnings Per Common Share-Diluted	$	2.93	$	0.53	$	2.45
	-1	Dilutive securities consist primarily of contingently convertible senior notes. See Note 17 for more information.

Investments_Tables

Investments (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]	'
Available-For-Sale Securities	'
	Dominion's decommissioning trust funds are summarized below:
		Amortized			Total			Total				Fair
		Cost			Unrealized			Unrealized				Value
					Gains (1)			Losses (1)
	(millions)
	2013
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,183		$	1,194		$	—			$	2,377
	Other	49			23			—				72
	Marketable debt securities:
	Corporate debt instruments	332			16			(3		)		345
	U.S. Treasury securities and agency debentures	589			8			(10		)		587
	State and municipal	297			11			(5		)		303
	Other	3			—			—				3
	Cost method investments	106			—			—				106
	Cash equivalents and other(2)	110			—			—				110
	Total	$	2,669		$	1,252		$	(18	)	(3)	$	3,903
	2012
	Marketable equity securities:
	U.S.:
	Large Cap	$	1,210		$	732		$	—			$	1,942
	Other	40			13			—				53
	Marketable debt securities:
	Corporate debt instruments	295			30			—				325
	U.S. Treasury securities and agency debentures	523			19			(2		)		540
	State and municipal	248			26			—				274
	Other	6			1			—				7
	Cost method investments	117			—			—				117
	Cash equivalents and other(2)	72			—			—				72
	Total	$	2,511		$	821		$	(2	)	(3)	$	3,330
	-1	Included in AOCI and the decommissioning trust regulatory liability as discussed in Note 2.
	-2	Includes pending sales of securities of $11 million and pending purchases of securities of $6 million at December 31, 2013 and 2012, respectively.
	-3	The fair value of securities in an unrealized loss position was $604 million and $195 million at December 31, 2013 and 2012, respectively.
Investments Classified by Contractual Maturity Date	'
	The fair value of Dominion's marketable debt securities held in nuclear decommissioning trust funds at December 31, 2013 by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	128
	Due after one year through five years	357
	Due after five years through ten years	362
	Due after ten years	391
	Total	$	1,238
Marketable Securities	'
	Presented below is selected information regarding Dominion's marketable equity and debt securities held in nuclear decommissioning trust funds:
	Year Ended December 31,	2013			2012			2011
	(millions)
	Proceeds from sales	$	1,476		$	1,356		$	1,757
	Realized gains(1)	157			98			79
	Realized losses(1)	33			33			92
	-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability as discussed in Note 2.
Other Than Temporary Impairment Losses On Investment Securities	'
	Dominion recorded other-than-temporary impairment losses on investments held in nuclear decommissioning trust funds as follows:
	Year Ended December 31,	2013			2012			2011
	(millions)
	Total other-than-temporary impairment losses(1)	$	31		$	26		$	75
	Losses recorded to decommissioning trust regulatory liability	(13		)	(10		)	(24		)
	Losses recognized in other comprehensive income (before taxes)	(10		)	(2		)	(3		)
	Net impairment losses recognized in earnings	$	8		$	14		$	48
	-1	Amounts include other-than-temporary impairment losses for debt securities of $18 million, $4 million and $6 million at December 31, 2013, 2012 and 2011, respectively.
Investments Accounts Under Equity Method of Accounting	'
	Investments that Dominion accounts for under the equity method of accounting are as follows:
	Company	Ownership%		Investment Balance						Description
	As of December 31,			2013			2012
	(millions)
	Blue Racer Midstream LLC	50	%	$	510		$	39		Midstream gas and related services
	Fowler I Holdings LLC	50	%	149			158			Wind-powered merchant generation facility
	NedPower Mount Storm LLC	50	%	131			137			Wind-powered merchant generation facility
	Iroquois Gas Transmission System, LP	24.72	%	105			102			Gas transmission system
	Elwood Energy LLC(1)	—	%	—			117			Natural gas-fired merchant generation peaking facility
	Other(2)	various		21			5
	Total			$	916		$	558
	(1) Following the 2013 sale of Elwood, at December 31, 2013, Dominion retained a 0.5% cost method investment. At December 31, 2012, Dominion owned 50% and Elwood was therefore considered an equity method investment.
	(2) Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018.
Virginia Electric and Power Company	'
Schedule of Available-for-sale Securities [Line Items]	'
Available-For-Sale Securities	'
	Virginia Power's decommissioning trust funds are summarized below:
		Amortized			Total			Total				Fair
		Cost			Unrealized			Unrealized				Value
					Gains (1)			Losses (1)
	(millions)
	2013
	Marketable equity securities:
	U.S.:
	Large Cap	$	506		$	514		$	—			$	1,020
	Other	25			11			—				36
	Marketable debt securities:
	Corporate debt instruments	185			8			(2		)		191
	U.S. Treasury securities and agency debentures	214			1			(3		)		212
	State and municipal	163			4			(4		)		163
	Cost method investments	106			—			—				106
	Cash equivalents and other(2)	37			—			—				37
	Total	$	1,236		$	538		$	(9	)	(3)	$	1,765
	2012
	Marketable equity securities:
	U.S.:
	Large Cap	$	481		$	298		$	—			$	779
	Other	20			7			—				27
	Marketable debt securities:
	Corporate debt instruments	179			17			—				196
	U.S. Treasury securities and agency debentures	231			4			(1		)		234
	State and municipal	106			11			—				117
	Other	1			—			—				1
	Cost method investments	117			—			—				117
	Cash equivalents and other(2)	44			—			—				44
	Total	$	1,179		$	337		$	(1	)	(3)	$	1,515
	-1	Included in AOCI and the decommissioning trust regulatory liability as discussed in Note 2.
	-2	Includes pending sales of securities of $6 million at December 31, 2013 and 2012.
	-3	The fair value of securities in an unrealized loss position was $299 million and $104 million at December 31, 2013 and 2012, respectively
Investments Classified by Contractual Maturity Date	'
	The fair value of Virginia Power's debt securities at December 31, 2013, by contractual maturity is as follows:
		Amount
	(millions)
	Due in one year or less	$	31
	Due after one year through five years	163
	Due after five years through ten years	196
	Due after ten years	176
	Total	$	566
Marketable Securities	'
	Presented below is selected information regarding Virginia Power's marketable equity and debt securities.
	Year Ended December 31,	2013			2012			2011
	(millions)
	Proceeds from sales	$	572		$	626		$	1,030
	Realized gains(1)	52			42			34
	Realized losses(1)	14			11			34
	-1	Includes realized gains and losses recorded to the decommissioning trust regulatory liability as discussed in Note 2
Other Than Temporary Impairment Losses On Investment Securities	'
	Virginia Power recorded other-than-temporary impairment losses on investments as follows:
	Year Ended December 31,	2013			2012			2011
	(millions)
	Total other-than-temporary impairment losses(1)	$	15		$	11		$	29
	Losses recorded to decommissioning trust regulatory liability	(13		)	(10		)	(24		)
	Losses recorded in other comprehensive income (before taxes)	(1		)	—			(1		)
	Net impairment losses recognized in earnings	$	1		$	1		$	4
	-1	Amounts include other-than-temporary impairment losses for debt securities of $9 million, $2 million and $4 million at December 31, 2013, 2012 and 2011, respectively

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment, Net [Abstract]	'
Property, Plant and Equipment	'
	Major classes of property, plant and equipment and their respective balances for the Companies are as follows:
	At December 31,	2013			2012
	(millions)
	Dominion
	Utility:
	Generation	$	14,018		$	13,707
	Transmission	8,686			7,799
	Distribution	11,714			11,071
	Storage	2,190			2,137
	Nuclear fuel	1,375			1,277
	Gas gathering and processing	787			803
	General and other	812			803
	Other-including plant under construction	3,261			2,232
	Total utility	42,843			39,829
	Nonutility:
	Merchant generation-nuclear	1,153			1,163
	Merchant generation-other(1)	1,328			1,289
	Nuclear fuel	770			775
	Other-including plant under construction	875			1,265
	Total nonutility	4,126			4,492
	Total property, plant and equipment	$	46,969		$	44,321
	Virginia Power
	Utility:
	Generation	$	14,018		$	13,707
	Transmission	4,959			4,261
	Distribution	9,103			8,701
	Nuclear fuel	1,375			1,277
	General and other	668			659
	Other-including plant under construction	2,719			2,017
	Total utility	32,842			30,622
	Nonutility-other	6			9
	Total property, plant and equipment	$	32,848		$	30,631
	-1	2012 amount includes $957 million due to consolidation of a VIE. See Note 15 for further information.
Share of Jointly-Owned Power Stations	'
	Dominion's and Virginia Power's proportionate share of jointly-owned power stations at December 31, 2013 is as follows:
		Bath			North			Clover			Millstone
		County			Anna Units 1 and 2(1)			Power			Unit 3(2)
		Pumped						Station(1)
		Storage
		Station(1)
	(millions, except percentages)
	Ownership interest	60		%	88.4		%	50		%	93.5		%
	Plant in service	$	1,038		$	2,486		$	568		$	1,007
	Accumulated depreciation	(536		)	(1,109		)	(199		)	(262		)
	Nuclear fuel	—			597			—			388
	Accumulated amortization of nuclear fuel	—			(434		)	—			(283		)
	Plant under construction	23			76			6			69
	-1	Units jointly owned by Virginia Power.
	-2	Unit jointly owned by Dominion.

Recovered_Sheet1

Goodwill And Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Segment allocation of goodwill	'
	The changes in Dominion's carrying amount and segment allocation of goodwill are presented below:
		Dominion				Dominion				DVP				Corporate		Total
		Generation				Energy								and
														Other(1)
	(millions)
	Balance at December 31, 2011(2)	$	1,503		(3)	$	712			$	926		(3)	$	—	$	3,141
	Asset disposition adjustment	—				(11		)	(5)	—				—		(11		)
	Balance at December 31, 2012(2)	$	1,503			$	701			$	926			$	—	$	3,130
	Asset disposition adjustment	(19		)	(4)	(25		)	(5)	—				—		(44		)
	Balance at December 31, 2013(2)	$	1,484			$	676			$	926			$	—	$	3,086
	-1	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.
	-2	Goodwill amounts do not contain any accumulated impairment losses.
	-3	Recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.
	-4	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
	-5	Related to assets sold or contributed to Blue Racer.
Components of intangible assets	'
	The components of intangible assets are as follows:
	At December 31,	2013						2012
		Gross			Accumulated			Gross			Accumulated
		Carrying			Amortization			Carrying			Amortization
		Amount						Amount
	(millions)
	Dominion
	Software, licenses and other	$	867		$	308		$	859		$	327
	Emissions allowances	3			2			5			1
	Total	$	870		$	310		$	864		$	328
	Virginia Power
	Software, licenses and other	$	271		$	78		$	303		$	122
	Total	$	271		$	78		$	303		$	122
Annual amortization expense of intangible assets	'
	Annual amortization expense for these intangible assets is estimated to be as follows:
		2014			2015			2016			2017			2018
	(millions)
	Dominion	$	69		$	59		$	50		$	40		$	29
	Virginia Power	$	21		$	15		$	12		$	9		$	5

Regulatory_Assets_and_Liabilit1

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets and Liabilities	'
	Regulatory assets and liabilities include the following:
	At December 31,	2013		2012
	(millions)
	Dominion
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	89	$	55
	Unrecovered gas costs(2)	50		59
	Virginia sales taxes(3)	46		37
	Derivatives(4)	16		—
	Plant retirement(5)	1		25
	Other	15		27
	Regulatory assets-current(6)	217		203
	Unrecognized pension and other postretirement benefit costs(7)	706		1,210
	Deferred rate adjustment clause costs(1)	287		173
	Income taxes recoverable through future rates(8)	155		140
	Derivatives(4)	16		105
	Other postretirement benefit costs(9)	12		21
	Plant retirement(5)	10		11
	Other	42		57
	Regulatory assets-non-current	1,228		1,717
	Total regulatory assets	$	1,445	$	1,920
	Regulatory liabilities:
	PIPP(10)	$	76	$	100
	Deferred cost of fuel used in electric generation(11)	24		7
	Other	28		29
	Regulatory liabilities-current(12)	128		136
	Provision for future cost of removal and AROs(13)	1,028		985
	Decommissioning trust(14)	693		501
	Unrecognized pension and other postretirement benefit costs(7)	174		2
	Deferred cost of fuel used in electric generation(11)	90		13
	Other	16		13
	Regulatory liabilities-non-current	2,001		1,514
	Total regulatory liabilities	$	2,129	$	1,650
	Virginia Power
	Regulatory assets:
	Deferred rate adjustment clause costs(1)	$	62	$	51
	Virginia sales taxes(3)	46		37
	Derivatives(4)	16		—
	Plant retirement(5)	1		25
	Other	3		6
	Regulatory assets-current	128		119
	Deferred rate adjustment clause costs(1)	227		127
	Income taxes recoverable through future rates(8)	124		110
	Derivatives(4)	16		105
	Plant retirement(5)	10		11
	Other	40		43
	Regulatory assets-non-current	417		396
	Total regulatory assets	$	545	$	515
	Regulatory liabilities:
	Deferred cost of fuel used in electric generation(11)	$	24	$	7
	Other	17		25
	Regulatory liabilities-current	41		32
	Provision for future cost of removal(13)	807		763
	Decommissioning trust(14)	693		501
	Deferred cost of fuel used in electric generation(11)	90		14
	Other	7		7
	Regulatory liabilities-non-current	1,597		1,285
	Total regulatory liabilities	$	1,638	$	1,317
	-1	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information.
	(2) Reflects unrecovered gas costs at Dominion's regulated gas operations, which are recovered through annual filings with the applicable regulatory authority.
	-3	Amounts to be recovered through an annual surcharge to reimburse Virginia Power for incremental sales taxes being incurred due to the repeal of the public service company sales tax exemption in Virginia.
	-4	As discussed under Derivative Instruments in Note 2, 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.
	-5	Reflects costs anticipated to be recovered in North Carolina base rates for certain coal units expected to be retired.
(6) Current regulatory assets are presented in other current assets in Dominion's Consolidated Balance Sheets.
-7	Represents unrecognized pension and other postretirement benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's rate-regulated subsidiaries.
-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	Primarily reflects costs recognized in excess of amounts included in regulated rates charged by Dominion's regulated gas operations before rates were updated to reflect a change in accounting method for other postretirement benefit costs.
-10	Under PIPP, eligible customers can receive energy assistance based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information regarding PIPP.
-11	Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Virginia Power's generation operations. For 2013, amount includes approximately $5 million related to DOE claims. See Note 13 for more information.
(12) Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
-13	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.
-14	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power's utility nuclear generation stations, in excess of the related ARO.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation [Abstract]	'
Changes to Asset Retirement Obligations	'
	The changes to AROs during 2012 and 2013 were as follows:
		Amount
	(millions)
	Dominion
	AROs at December 31, 2011(1)	$	1,398
	Obligations incurred during the period	24
	Obligations settled during the period	(13		)
	Revisions in estimated cash flows(2)	242
	Accretion	77
	Other	(23		)
	AROs at December 31, 2012(1)	$	1,705
	Obligations incurred during the period	13
	Obligations settled during the period	(68		)
	Revisions in estimated cash flows(3)	(129		)
	Accretion	86
	Other	(29		)
	AROs at December 31, 2013(1)	$	1,578
	Virginia Power
	AROs at December 31, 2011(4)	$	625
	Obligations incurred during the period	18
	Obligations settled during the period	(1		)
	Revisions in estimated cash flows(5)	41
	Accretion	34
	Other	(12		)
	AROs at December 31, 2012	$	705
	Obligations incurred during the period	2
	Obligations settled during the period	(2		)
	Revisions in estimated cash flows(3)	(52		)
	Accretion	38
	Other	(2		)
	AROs at December 31, 2013	$	689
	-1	Includes $15 million, $64 million and $94 million reported in other current liabilities at December 31, 2011, 2012, and 2013, respectively.
	-2	Primarily reflects the accelerated timing of the decommissioning of Kewaunee that began in 2013.
	-3	Primarily reflects lower anticipated nuclear decommissioning costs.
	-4	Includes $1 million reported in other current liabilities.
	-5	Primarily reflects the effect of higher anticipated nuclear decommissioning costs.

ShortTerm_Debt_And_Credit_Agre1

Short-Term Debt And Credit Agreements (Tables)	12 Months Ended
	Dec. 31, 2013
Short term Debt [Line Items]	'
Commercial paper bank loans and letters of credit outstanding as well as capacity available under credit facilities	'
	Commercial paper and letters of credit outstanding, as well as capacity available under credit facilities, were as follows:
		Facility		Outstanding			Outstanding		Facility
		Limit		Commercial			Letters of		Capacity
				Paper			Credit		Available
	(millions)
	At December 31, 2013
	Joint revolving credit facility(1)	$	3,000	$	1,927		$	—	$	1,073
	Joint revolving credit facility(2)	500		—			11		489
	Total	$	3,500	$	1,927	(3)	$	11	$	1,562
	At December 31, 2012
	Joint revolving credit facility(1)	$	3,000	$	2,412		$	—	$	588
	Joint revolving credit facility(2)	500		—			26		474
	Total	$	3,500	$	2,412	(3)	$	26	$	1,062
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit.
	-2	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by Dominion's credit facilities were 0.33% and 0.49% at December 31, 2013 and 2012, respectively.
Virginia Electric and Power Company	'
Short term Debt [Line Items]	'
Commercial paper bank loans and letters of credit outstanding as well as capacity available under credit facilities	'
	Virginia Power's share of commercial paper and letters of credit outstanding, as well as its capacity available under its joint credit facilities with Dominion, were as follows:
		Facility Sub-limit		Outstanding Commercial Paper			Outstanding Letters of Credit		Facility Sub-limit Capacity Available
	(millions)
	At December 31, 2013
	Joint revolving credit facility(1)	$	1,000	$	842		$	—	$	158
	Joint revolving credit facility(2)	250		—			1		249
	Total	$	1,250	$	842	(3)	$	1	$	407
	At December 31, 2012
	Joint revolving credit facility(1)	$	1,000	$	992		$	—	$	8
	Joint revolving credit facility(2)	250		—			2		248
	Total	$	1,250	$	992	(3)	$	2	$	256
	-1	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility 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. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.
	-2	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.
	-3	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.33% and 0.47% at December 31, 2013 and 2012, respectively.

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Long term Debt	'
	At December 31,	2013 Weighted-		2013			2012
		average
		Coupon(1)
	(millions, except percentages)
	Virginia Electric and Power Company:
	Unsecured Senior Notes:
	1.2% to 8.625%, due 2013 to 2018	5.09	%	$	2,138		$	2,306
	2.75% to 8.875%, due 2019 to 2043	5.25	%	4,993			3,408
	Tax-Exempt Financings(2):
	Variable rates, due 2016 to 2041	0.98	%	606			454
	1.5% to 5.6%, due 2022 to 2040	3.16	%	306			508
	Virginia Electric and Power Company total principal			$	8,043		$	6,676
	Securities due within one year	4.1	%	(58		)	(418		)
	Unamortized discount and premium, net			(11		)	(7		)
	Virginia Electric and Power Company total long-term debt			$	7,974		$	6,251
	Dominion Resources, Inc.:
	Unsecured Senior Notes:
	Variable rates, due 2013 and 2014	0.37	%	$	400		$	400
	1.4% to 7.195%, due 2013 to 2018	4.03	%	3,291			3,541
	2.75% to 8.875%, due 2019 to 2042(3)	5.64	%	4,599			4,599
	Unsecured Convertible Senior Notes, 2.125%, due 2023(4)			43			82
	Tax-Exempt Financing, variable rate, due 2041(5)	1.12	%	75			—
	Unsecured Junior Subordinated Notes Payable to Affiliated Trusts, 7.83% and 8.4%, due 2027 and 2031	8.4	%	10			268
	Enhanced Junior Subordinated Notes:
	7.5% and 8.375%, due 2064 and 2066	8.11	%	985			985
	Variable rate, due 2066	2.58	%	380			380
	Remarketable Subordinated Notes, 1.07% and 1.18%, due 2019 and 2021	1.13	%	1,100			—
	Unsecured Debentures and Senior Notes(6):
	5.0% and 6.625%, due 2013 and 2014	5	%	600			622
	6.8% and 6.875%, due 2026 and 2027	6.81	%	89			89
	Dominion Gas Holdings, LLC:
	Unsecured Senior Notes, 1.05% to 4.8%, due 2016 to 2043	3.13	%	1,200			—
	Dominion Energy, Inc.:
	Secured Senior Notes:
	5.03% to 5.78%, due 2013(7)			—			842
	7.33%, due 2020(8)			—			145
	Tax-Exempt Financings:
	2.25% to 5.75%, due 2033 to 2042(9)	2.38	%	27			284
	Variable rate, due 2041(5)			—			75
	Virginia Electric and Power Company total principal (from above)			8,043			6,676
	Dominion Resources, Inc. total principal			$	20,842		$	18,988
	Fair value hedge valuation(10)			55			93
	Securities due within one year(11)	2.95	%	(1,519		)	(2,223		)
	Unamortized discount and premium, net			(48		)	(7		)
	Dominion Resources, Inc. total long-term debt			$	19,330		$	16,851
	-1	Represents weighted-average coupon rates for debt outstanding as of December 31, 2013.
	-2	These financings relate to certain pollution control equipment at Virginia Power's generating facilities. Certain variable rate tax-exempt financings are supported by a $120 million credit facility that terminates in September 2018.
	-3	At the option of holders, $510 million of Dominion's 5.25% senior notes due 2033 and $600 million of Dominion's 8.875% senior notes due 2019 are subject to redemption at 100% of the principal amount plus accrued interest in August 2015 and January 2014, respectively.
	-4	Convertible into a combination of cash and shares of Dominion's common stock at any time when the closing price of common stock equals 120% of the applicable conversion price or higher for at least 20 out of the last 30 consecutive trading days ending on the last trading day of the previous calendar quarter. At the option of holders on December 15, 2018, these securities are subject to redemption at 100% of the principal amount plus accrued interest. These senior notes have been callable by Dominion since December 15, 2011.
	-5	Debt issued by the MDFA on behalf of Brayton Point. In connection with the sale of Brayton Point, the sole obligor under the bonds was changed from Brayton Point to Dominion in June 2013.
	-6	Represents debt assumed by Dominion from the merger of its former CNG subsidiary.
	-7	Juniper notes issued in 2004 and consolidated in October 2011 due to Dominion becoming the primary beneficiary of this VIE. This amount excludes $18 million of unamortized premium in 2012. The debt was non-recourse to Dominion and was secured by Juniper's assets. Dominion's purchase of Fairless in August 2013 resulted in the removal of the debt from Dominion's Consolidated Balance Sheet. See Note 15 for additional information.
	-8	Represented debt associated with Kincaid. The debt was non-recourse to Dominion and was secured by the facility's assets and revenue. In connection with the sale of Kincaid, the notes were redeemed in May 2013 for approximately $185 million, including a make-whole premium and accrued interest.
	-9	In 2012 included debt issued by the MDFA on behalf of Brayton Point. In connection with the sale of Brayton Point, three series of bonds totaling approximately $257 million were defeased in June 2013. In June 2013, Brayton Point delivered approximately $284 million to fund an irrevocable trust for the purpose of paying maturing principal and interest due through and including the earliest redemption dates of the bonds in 2016 and 2019.
	-10	Represents the valuation of certain fair value hedges associated with Dominion's fixed rate debt.
	-11	Includes $14 million fair value hedge valuation in 2013 and $23 million of net unamortized premium and fair value hedge valuation in 2012.
Scheduled principal payments of long-term debt	'
	Based on stated maturity dates rather than early redemption dates that could be elected by instrument holders, the scheduled principal payments of long-term debt at December 31, 2013, were as follows:
		2014			2015			2016			2017			2018			Thereafter			Total
	(millions, except percentages)
	Virginia Power	$	58		$	211		$	476		$	679		$	850		$	5,769		$	8,043
	Weighted-average Coupon	4.1		%	5.39		%	5.25		%	5.44		%	4.17		%	4.78		%
	Dominion
	Unsecured Senior Notes	$	1,465		$	960		$	1,752		$	1,303		$	1,350		$	10,523		$	17,353
	Tax-Exempt Financings	40			—			19			75			—			880			1,014
	Unsecured Junior Subordinated Notes Payable to Affiliated Trusts	—			—			—			—			—			10			10
	Enhanced Junior Subordinated Notes	—			—			—			—			—			1,365			1,365
	Remarketable Subordinated Notes	—			—			—			—			—			1,100			1,100
	Total	$	1,505		$	960		$	1,771		$	1,378		$	1,350		$	13,878		$	20,842
	Weighted-average Coupon	2.95		%	4.45		%	3.51		%	4.55		%	4.99		%	4.9		%
Trust preferred securities and junior subordinated notes outstanding text block	'
	The following table provides summary information about the capital securities and junior subordinated notes outstanding as of December 31, 2013:
	Date Established	Capital Trust	Units		Rate		Capital Securities Amount			Common Securities Amount
			(thousands)				(millions)
	Jan-01	Dominion Resources Capital Trust III(1)	10		8.4	%	$	10		$	0.3
	-1	$10 million-Dominion Resources, Inc. 8.4% Debentures due 1/15/2031 were held as assets by the capital trust.
Schedule of Capital Units	'
	Selected information about Dominion's Equity Units is presented below:
	Issuance Date	Units Issued	Total Net Proceeds			Total Long-term Debt			RSN Annual Interest Rate		Stock Purchase Contract Annual Rate		Stock Purchase Contract Liability(1)			Stock Purchase Settlement Date	RSN Maturity Date
	(millions, except interest rates)
	6/7/13	11	$	533.5		$	550		1.07	%	5.055	%	$	76.7		4/1/16	4/1/21
	6/7/13	11	$	553.5		$	550		1.18	%	4.82	%	$	79.3		7/1/16	7/1/19
	-1	Payments of $17 million were made in 2013. The stock purchase contract liability was $139 million at December 31, 2013.

Preferred_Stock_Tables

Preferred Stock (Tables)	12 Months Ended
	Dec. 31, 2013
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]	'
Schedule Of Preferred Stock	'
	Presented below are the series of Virginia Power preferred stock that were outstanding as of December 31, 2013:
	Dividend	Issued and Outstanding Shares	Entitled Per  Share Upon Liquidation
		(thousands)
	$5.00	107	$	112.5
	4.04	13	102.27
	4.2	15	102.5
	4.12	32	103.73
	4.8	73	101
	7.05	500	100
	6.98	600	100
	Flex Money Market Preferred 12/02, Series A	1,250	100		(1)
	Total	2,590
	-1	Effective March 20, 2011 the rate was reset to 6.12% until March 20, 2014 after which the rate

Shareholders_Equity_Tables

Shareholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Accumulated other comprehensive income (loss)	'
	Presented in the table below is a summary of AOCI by component:
	At December 31,	2013			2012
	(millions)
	Dominion
	Net deferred losses on derivatives-hedging activities, net of tax of $196 and $87	$	(288	)	$	(122	)
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(307) and $(206)	474			326
	Net unrecognized pension and other postretirement benefit costs, net of tax of $365 and $745	(510		)	(1,081		)
	Total AOCI	$	(324	)	$	(877	)
	Virginia Power
	Net deferred losses on derivatives-hedging activities, net of tax of $-- and $3	$	—		$	(6	)
	Net unrealized gains on nuclear decommissioning trust funds, net of tax of $(30) and $(19)	48			31
	Total AOCI	$	48		$	25
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			Total
	(millions)
	Year Ended December 31, 2013
	Beginning balance	$	(122	)	$	326		$	(1,081	)	$	(877	)
	Other comprehensive income before reclassifications: gains (losses)	(243		)	203			516			476
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	77			(55		)	55			77
	Net current period other comprehensive income (loss)	(166		)	148			571			553
	Ending balance	$	(288	)	$	474		$	(510	)	$	(324	)
	(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)
	Year Ended December 31, 2013
	Deferred (gains) and losses on derivatives-hedging activities:
	Commodity contracts	$	58		Operating revenue
		47			Purchased gas
		10			Electric fuel and other energy-related purchases
	Interest rate contracts	15			Interest and related charges
	Total	130
	Tax	(53		)	Income tax expense
	Total, net of tax	$	77
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(98	)	Other income
	Impairment	8			Other income
	Total	(90		)
	Tax	35			Income tax expense
	Total, net of tax	$	(55	)
	Unrecognized pension and other postretirement benefit costs:
	Prior-service costs (credits)	$	(8	)	Other operations and maintenance
	Actuarial losses	102			Other operations and maintenance
	Total	94
	Tax	(39		)	Income tax expense
	Total, net of tax	$	55
Summary of changes in amounts of stock options outstanding	'
	The following table provides a summary of changes in amounts of stock options outstanding as of and for the years ended December 31, 2012 and 2011. There were no stock options outstanding in 2013. No options were granted under any plan in 2013, 2012 or 2011.
		Shares		Weighted -			Weighted -	Aggregated
				average			average	Intrinsic
				Exercise Price			Remaining	Value(1)
							Contractual
							Life
		(thousands)					(years)	(millions)
	Outstanding and exercisable at December 31, 2010	1,810		$	31.76			20
	Exercised	(1,174	)	$	32.46			$	17
	Forfeited/expired	(8	)	$	31.57
	Outstanding and exercisable at December 31, 2011	628		$	30.81			$	14
	Exercised	(622	)	$	30.79			$	13
	Forfeited/expired	(6	)	$	32.26
	Outstanding and exercisable at December 31, 2012	—		$	—			$	—
	-1	Intrinsic value represents the difference between the exercise price of the option and the market value of Dominion's stock.
Summary of restricted stock activity	'
	The following table provides a summary of restricted stock activity for the years ended December 31, 2013, 2012 and 2011:
		Shares		Weighted
				- average
				Grant Date
				Fair Value
		(thousands)
	Nonvested at December 31, 2010	1,476		$	38.2
	Granted	299		43.68
	Vested	(617	)	40.72
	Cancelled and forfeited	(25	)	36.29
	Converted from goal-based stock to restricted stock	168		30.99
	Nonvested at December 31, 2011	1,301		$	37.37
	Granted	390		51.14
	Vested	(596	)	33.31
	Cancelled and forfeited	(10	)	42.99
	Nonvested at December 31, 2012	1,085		$	44.46
	Granted	312		54.7
	Vested	(356	)	39
	Cancelled and forfeited	(34	)	51.11
	Nonvested at December 31, 2013	1,007		$	49.35
Summary of restricted stock and goal-based stock activity	'
	The following table provides a summary of goal-based stock activity for the years ended December 31, 2013, 2012 and 2011:
		Targeted		Weighted
		Number of		- average
		Shares		Grant
				Date Fair
				Value
		(thousands)
	Nonvested at December 31, 2010	161		$	31.79
	Granted	3		43.54
	Vested	(20	)	34.62
	Cancelled and forfeited	(132	)	30.99
	Nonvested at December 31, 2011	12		$	39.19
	Granted	1		52.48
	Vested	(9	)	37.46
	Nonvested at December 31, 2012	4		$	45.6
	Granted	4		54.17
	Vested	(2	)	43.54
	Cancelled and forfeited	(1	)	43.54
	Nonvested at December 31, 2013	5		$	53.85
Virginia Electric and Power Company	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	The following table presents Virginia Power’s changes in AOCI by component, net of tax:
		Deferred gains and losses on derivatives-hedging activities			Unrealized gains and losses on nuclear decommissioning trust funds			Total
	(millions)
	Year Ended December 31, 2013
	Beginning balance	$	(6	)	$	31		$	25
	Other comprehensive income before reclassifications: gains (losses)	6			20			26
	Amounts reclassified from accumulated other comprehensive income: (gains) losses(1)	—			(3		)	(3		)
	Net current period other comprehensive income (loss)	6			17			23
	Ending balance	$	—		$	48		$	48
	(1) See table below for details about these reclassifications.
Reclassification out of Accumulated Other Comprehensive Income	'
	The following table presents Virginia Power’s reclassifications out of AOCI by component:
	Details about AOCI components	Amounts reclassified from AOCI			Affected line item in the Consolidated Statements of Income
	(millions)
	Year Ended December 31, 2013
	Unrealized (gains) and losses on investment securities:
	Realized (gain) loss on sale of securities	$	(6	)	Other income
	Impairment	1			Other income
	Total	(5		)
	Tax	2			Income tax expense
	Total, net of tax	$	(3	)

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2013
General Discussion of Pension and Other Postretirement Benefits [Abstract]	'
Pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans funded status	'
	The following table summarizes the changes in Dominion's pension plan and other postretirement benefit plan obligations and plan assets and includes a statement of the plans' funded status:
		Pension Benefits						Other Postretirement
								Benefits
	Year Ended December 31,	2013			2012			2013			2012
	(millions, except percentages)
	Changes in benefit obligation:
	Benefit obligation at beginning of year	$	6,125		$	4,981		$	1,719		$	1,493
	Service cost	131			116			43			44
	Interest cost	271			268			73			79
	Benefits paid	(229		)	(208		)	(75		)	(88		)
	Actuarial (gains) losses during the year	(650		)	967			(170		)	191
	Plan amendments(1)	1			1			(220		)	1
	Settlements and curtailments(2)	(24		)	—			(16		)	(6		)
	Special termination benefits	—			—			1			—
	Medicare Part D reimbursement	—			—			5			5
	Benefit obligation at end of year	$	5,625		$	6,125		$	1,360		$	1,719
	Changes in fair value of plan assets:
	Fair value of plan assets at beginning of year	$	5,553		$	5,145		$	1,156		$	1,042
	Actual return on plan assets	781			611			178			132
	Employer contributions	8			5			12			16
	Benefits paid	(229		)	(208		)	(31		)	(34		)
	Fair value of plan assets at end of year	$	6,113		$	5,553		$	1,315		$	1,156
	Funded status at end of year	$	488		$	(572	)	$	(45	)	$	(563	)
	Amounts recognized in the Consolidated Balance Sheets at December 31:
	Noncurrent pension and other postretirement benefit assets	$	913		$	701		$	29		$	1
	Other current liabilities	(15		)	(2		)	(3		)	(4		)
	Noncurrent pension and other postretirement benefit liabilities	(410		)	(1,271		)	(71		)	(560		)
	Net amount recognized	$	488		$	(572	)	$	(45	)	$	(563	)
	Significant assumptions used to determine benefit obligations as of December 31:
	Discount rate(3)	5.20%/5.30%			4.4		%	5.00%/5.10%			4.4		%
	Weighted average rate of increase for compensation	4.21		%	4.21		%	4.22		%	4.22		%
	-1	Relates to a plan amendment that changed medical coverage for certain Medicare-eligible retirees.
	-2	2013 amounts relate primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.
	-3	Pension rates are 5.20% for the gas union plans and 5.30% for the nonunion and other union plans. OPEB rates are 5.00% for the gas union plans and 5.10% for the nonunion and other union plans.
Benefit obligation in excess of plan asset	'
	The following table provides information on the benefit obligations and fair value of plan assets for plans with a benefit obligation in excess of plan assets:
		Pension Benefits								Other Postretirement
										Benefits
	As of December 31,	2013				2012				2013			2012
	(millions)
	Benefit obligation	$	4,978			$	5,462			$	1,233		$	1,591
	Fair value of plan assets	4,553				4,189				1,158			1,027
Accumulated benefit obligation in excess of plan assets	'
	The following table provides information on the ABO and fair value of plan assets for pension plans with an ABO in excess of plan assets:
	As of December 31,	2013			2012
	(millions)
	Accumulated benefit obligation	$	114		$	4,850
	Fair value of plan assets	—			4,189
Benefit payments expected future service	'
	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid:
		Estimated Future Benefit Payments
		Pension Benefits			Other  Postretirement Benefits
	(millions)
	2014	$	264		$	91
	2015	269			93
	2016	283			96
	2017	300			98
	2018	319			100
	2019-2023	1,868			507
Fair values of pension and post retirement plan assets by asset category	'
	The fair values of Dominion's pension plan assets by asset category are as follows:
		Fair Value Measurements
		Pension Plans
	At December 31,	2013												2012
		Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	(millions)
	Cash equivalents	$	53		$	126		—			$	179		—			$	195		—			$	195
	U.S. equity:
	Large Cap	1,220			—			—			1,220			927			104			—			1,031
	Other	514			—			—			514			425			99			—			524
	Non-U.S. equity:
	Large Cap	308			—			—			308			313			68			—			381
	Other	391			—			—			391			228			167			—			395
	Common/collective trust funds	—			1,387			—			1,387			—			—			—			—
	Fixed income:
	Corporate debt instruments	43			451			—			494			27			1,026			—			1,053
	U.S. Treasury securities and agency debentures	2			229			—			231			331			304			—			635
	State and municipal	69			107			—			176			1			71			—			72
	Other securities	7			50			—			57			5			43			—			48
	Real estate:
	REITs	32			—			—			32			29			—			—			29
	Partnerships	—			—			227			227			—			—			321			321
	Other alternative investments:
	Private equity	—			—			530			530			—			—			456			456
	Debt	—			—			180			180			—			—			192			192
	Hedge funds	—			—			187			187			—			—			221			221
	Total	$	2,639		$	2,350		$	1,124		$	6,113		$	2,286		$	2,077		$	1,190		$	5,553
	The fair values of Dominion's other postretirement plan assets by asset category are as follows:
		Fair Value Measurements
		Other Postretirement Plans
	At December 31,	2013												2012
		Level 1			Level 2			Level 3			Total			Level 1			Level 2			Level 3			Total
	(millions)
	Cash equivalents	$	3		$	14		$	—		$	17		$	—		$	13		$	—		$	13
	U.S. equity:
	Large Cap	472			—			—			472			378			5			—			383
	Other	26			—			—			26			21			45			—			66
	Non-U.S. equity:
	Large Cap	111			—			—			111			93			3			—			96
	Other	20			—			—			20			11			8			—			19
	Common/collective trust funds	—			502			—			502			—			—			—			—
	Fixed income:
	Corporate debt instruments	2			23			—			25			1			160			—			161
	U.S. Treasury securities and agency debentures	—			12			—			12			16			266			—			282
	State and municipal	4			5			—			9			—			9			—			9
	Other securities	—			3			—			3			—			2			—			2
	Real estate:
	REITs	2			—			—			2			1			—			—			1
	Partnerships	—			—			19			19			—			—			24			24
	Other alternative investments:
	Private equity	—			—			60			60			—			—			58			58
	Debt	—			—			27			27			—			—			31			31
	Hedge funds	—			—			10			10			—			—			11			11
	Total	$	640		$	559		$	116		$	1,315		$	521		$	511		$	124		$	1,156
Pension plan and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category	'
	The following table presents the changes in Dominion's pension and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category:
		Fair Value Measurements using Significant Unobservable Inputs (Level 3)
		Pension Plans															Other Postretirement Plans
		Real Estate			Private Equity			Debt			Hedge Funds			Total			Real Estate			Private Equity			Debt			Hedge Funds			Total
	Balance at December 31, 2010	$	271		$	400		$	262		$	345		$	1,278		$	22		$	61		$	40		$	17		$	140
	Actual return on plan assets:
	Relating to assets still held at the reporting date	38			70			10			10			128			3			11			1			—			15
	Relating to assets sold during the period	(8		)	(34		)	(10		)	(15		)	(67		)	—			(4		)	(1		)	(1		)	(6		)
	Purchases	57			76			34			48			215			3			8			3			2			16
	Sales	(54		)	(64		)	(53		)	(98		)	(269		)	(4		)	(13		)	(7		)	(4		)	(28		)
	Balance at December 31, 2011	$	304		$	448		$	243		$	290		$	1,285		$	24		$	63		$	36		$	14		$	137
	Actual return on plan assets:
	Relating to assets still held at the reporting date	21			46			17			21			105			1			3			4			1			9
	Relating to assets sold during the period	(8		)	(41		)	(11		)	(2		)	(62		)	—			(1		)	—			—			(1		)
	Purchases	35			79			15			—			129			2			6			1			—			9
	Sales	(31		)	(76		)	(72		)	(88		)	(267		)	(3		)	(13		)	(10		)	(4		)	(30		)
	Balance at December 31, 2012	$	321		$	456		$	192		$	221		$	1,190		$	24		$	58		$	31		$	11		$	124
	Actual return on plan assets:
	Relating to assets still held at the reporting date	15			98			32			21			166			(2		)	6			3			1			8
	Relating to assets sold during the period	(36		)	(48		)	(34		)	(4		)	(122		)	1			3			—			1			5
	Purchases	6			115			32			—			153			1			7			2			—			10
	Sales	(79		)	(91		)	(42		)	(51		)	(263		)	(5		)	(14		)	(9		)	(3		)	(31		)
	Balance at December 31, 2013	$	227		$	530		$	180		$	187		$	1,124		$	19		$	60		$	27		$	10		$	116
Net periodic benefit (credit) cost and amounts recognized in other comprehensive income and regulatory assets and liabilities	'
	The components of the provision for net periodic benefit cost and amounts recognized in other comprehensive income and regulatory assets and liabilities are as follows:
		Pension Benefits									Other Postretirement Benefits
	Year Ended December 31,	2013			2012			2011			2013			2012			2011
	(millions, except percentages)
	Service cost	$	131		$	116		$	108		$	43		$	44		$	48
	Interest cost	271			268			258			73			79			94
	Expected return on plan assets	(462		)	(430		)	(440		)	(92		)	(79		)	(79		)
	Amortization of prior service (credit) cost	3			3			3			(15		)	(13		)	(13		)
	Amortization of net actuarial loss	165			132			96			7			6			12
	Settlements and curtailments(1)	(2		)	—			—			(15		)	(4		)	1
	Special termination benefits	—			—			—			1			—			—
	Net periodic benefit cost	$	106		$	89		$	25		$	2		$	33		$	63
	Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:
	Current year net actuarial (gain) loss	$	(968	)	$	786		$	534		$	(255	)	$	139		$	(157	)
	Prior service (credit) cost	1			—			—			(215		)	1			(70		)
	Settlements and curtailments(1)	(22		)	—			—			(7		)	(2		)	(1		)
	Less amounts included in net periodic benefit cost:
	Amortization of net actuarial loss	(165		)	(132		)	(96		)	(7		)	(6		)	(12		)
	Amortization of prior service credit (cost)	(3		)	(3		)	(3		)	15			13			13
	Total recognized in other comprehensive income and regulatory assets and liabilities	$	(1,157	)	$	651		$	435		$	(469	)	$	145		$	(227	)
	Significant assumptions used to determine periodic cost:
	Discount rate	4.40% - 4.80%			5.5		%	5.9		%	4.40% - 4.80%			5.5		%	5.9		%
	Expected long-term rate of return on plan assets	8.5		%	8.5		%	8.5		%	7.75		%	7.75		%	7.75		%
	Weighted average rate of increase for compensation	4.21		%	4.21		%	4.61		%	4.22		%	4.22		%	4.62		%
	Healthcare cost trend rate(2)										7		%	7		%	7		%
	Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)(2)										4.6		%	4.6		%	4.6		%
	Year that the rate reaches the ultimate trend rate(2)										2062			2061			2060
	-1	2013 amount relates primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.
	-2	Assumptions used to determine periodic cost for the following year.
Components of AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost	'
	The components of AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost are as follows:
		Pension Benefits						Other
								Postretirement
								Benefits
	At December 31,	2013			2012			2013			2012
	(millions)
	Net actuarial (gain) loss	$	1,709		$	2,865		$	(40	)	$	229
	Prior service (credit) cost	10			11			(271		)	(71		)
	Total(1)	$	1,719		$	2,876		$	(311	)	$	158
	-1	As of December 31, 2013, of the $1.7 billion and $(311) million related to pension benefits and other postretirement benefits, $1.0 billion and $(156) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2012, of the $2.9 billion and $158 million related to pension benefits and other postretirement benefits, $1.8 billion and $69 million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.
Components of AOCI and regulatory assets and liabilities that are expected to be amortized as components of periodic benefit cost in 2014	'
	The following table provides the components of AOCI and regulatory assets and liabilities as of December 31, 2013 that are expected to be amortized as components of periodic benefit cost in 2014:
		Pension			Other
		Benefits			Postretirement
					Benefits
	(millions)
	Net actuarial loss	$	112		$	2
	Prior service (credit) cost	3			(28		)
Effect of one percentage point change on benefit plans	'
	A one percentage point change in assumed healthcare cost trend rates would have had the following effects:
		Other Postretirement Benefits
		One percentage point increase			One percentage point decrease
	(millions)
	Effect on net periodic cost for 2014	$	16		$	(18	)
	Effect on other postretirement benefit obligation at December 31, 2013	140			(118		)

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Loss Contingencies [Line Items]	'
Nuclear Insurance	'
	Effective June 7, 2013 for Kewaunee and July 1, 2013 for Millstone and Virginia Power's nuclear units, the levels of nuclear property insurance coverage were reduced to the following:
		Coverage
	(billions)
	Dominion
	Millstone	$	1.7
	Kewaunee	1.06
	Virginia Power(1)
	Surry	$	1.7
	North Anna	1.7
	-1	Surry and North Anna share a blanket property limit of $450 million.
Lease Commitments	'
	Future minimum lease payments under noncancelable operating and capital leases that have initial or remaining lease terms in excess of one year as of December 31, 2013 are as follows:
		2014		2015		2016		2017		2018		Thereafter		Total
	(millions)
	Dominion	$	63	$	60	$	51	$	43	$	37	$	87	$	341
	Virginia Power	$	27	$	26	$	21	$	17	$	14	$	27	$	132
Subsidiary guarantees	'
	At December 31, 2013, Dominion had issued the following subsidiary guarantees:
		Stated Limit		Value(1)
	(millions)
	Subsidiary debt(2)	$	27	$	27
	Commodity transactions(3)	3,158		403
	Nuclear obligations(4)	232		68
	Cove Point(5)	335		—
	Other(6)	669		108
	Total	$	4,421	$	606
	-1	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2013 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 energy trading and marketing activities and other commodity commitments of certain subsidiaries, including subsidiaries of Virginia Power 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 and Kewaunee, respectively, in the event of a prolonged outage, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee also provides for funds through the completion of decommissioning.
	-5	Guarantees related to Cove Point, including agreements to support terminal service and transportation agreements as well as an engineering, procurement and construction contract for new liquefaction facilities. Includes certain guarantees that do not have stated limits.
	-6	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.
Virginia Electric and Power Company	'
Loss Contingencies [Line Items]	'
Long-term Purchase Commitment	'
	At December 31, 2013, Virginia Power had the following long-term commitments that are noncancelable or are cancelable only under certain conditions, and that third parties have used to secure financing for the facilities that will provide the contracted goods or services:
		2014		2015		2016		2017		2018		Thereafter		Total
	(millions)
	Purchased electric capacity(1)	$	336	$	316	$	253	$	159	$	104	$	163	$	1,331
	-1	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities and independent power producers, the last of which ends in 2021. Capacity payments under the contracts are generally based on fixed dollar amounts per month, subject to escalation using broad-based economic indices. At December 31, 2013, the present value of Virginia Power's total commitment for capacity payments is $1.1 billion. Capacity payments totaled $345 million, $337 million, and $338 million, and energy payments totaled $236 million, $214 million, and $275 million for 2013, 2012 and 2011, respectively.

Related_Party_Transactions_Tab

Related Party Transactions (Tables) (Virginia Electric and Power Company)	12 Months Ended
	Dec. 31, 2013
Virginia Electric and Power Company	'
Related Party Transaction [Line Items]	'
Schedules Of Transactions With Affiliates	'
	Presented below are significant transactions with DRS and other affiliates:
	Year Ended December 31,	2013		2012		2011
	(millions)
	Commodity purchases from affiliates	$	417	$	368	$	376
	Services provided by affiliates	415		399		393
	Services provided to affiliates	21		19		21

Operating_Segments_Tables

Operating Segments (Tables)	12 Months Ended
	Dec. 31, 2013
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	Description of Operations	Dominion	Virginia
	Segment			Power
	DVP	Regulated electric distribution	X	X
		Regulated electric transmission	X	X
	Dominion Generation	Regulated electric fleet	X	X
		Merchant electric fleet	X
		Nonregulated retail energy marketing (electric and gas)(1)	X
	Dominion Energy	Gas transmission and storage	X
		Gas distribution and storage	X
		LNG services	X
		Producer services	X
	-1	As a result of Dominion's decision to realign its business units effective for 2013 year-end reporting, nonregulated retail energy marketing operations were moved from DVP to the Dominion Generation segment.
Schedule of Segment Reporting Information, by Segment	'
	The following table presents segment information pertaining to Dominion's operations:
	Year Ended December 31,	DVP(1)			Dominion			Dominion			Corporate and			Adjustments &			Consolidated
					Generation(1)(2)			Energy			Other(2)			Eliminations(1)			Total
	(millions)
	2013
	Total revenue from external customers	$	1,825		$	8,445		$	1,783		$	3		$	1,064		$	13,120
	Intersegment revenue	9			68			1,063			609			(1,749		)	—
	Total operating revenue	1,834			8,513			2,846			612			(685		)	13,120
	Depreciation, depletion and amortization	427			518			228			35			—			1,208
	Equity in earnings of equity method investees	—			(14		)	21			7			—			14
	Interest income	—			66			12			42			(66		)	54
	Interest and related charges	175			220			26			522			(66		)	877
	Income taxes	287			483			409			(287		)	—			892
	Loss from discontinued operations, net of tax	—			—			—			(92		)	—			(92		)
	Net income (loss) attributable to Dominion	475			1,031			643			(452		)	—			1,697
	Investment in equity method investees	—			280			615			21			—			916
	Capital expenditures	1,361			1,605			1,043			95			—			4,104
	Total assets (billions)	11.9			22			12.1			8.5			(4.4		)	50.1
	2012
	Total revenue from external customers	$	1,846		$	8,170		$	1,813		$	155		$	851		$	12,835
	Intersegment revenue	9			104			930			608			(1,651		)	—
	Total operating revenue	1,855			8,274			2,743			763			(800		)	12,835
	Depreciation, depletion and amortization	392			483			216			36			—			1,127
	Equity in earnings of equity method investees	—			3			23			(1		)	—			25
	Interest income	1			65			30			71			(106		)	61
	Interest and related charges	187			177			47			511			(106		)	816
	Income taxes	278			576			352			(395		)	—			811
	Loss from discontinued operations, net of tax	—			—			—			(1,125		)	—			(1,125		)
	Net income (loss) attributable to Dominion	439			1,021			551			(1,709		)	—			302
	Investment in equity method investees	—			414			141			3			—			558
	Capital expenditures	1,158			1,615			1,350			22			—			4,145
	Total assets (billions)	11.5			21.8			11.2			12.6			(10.3		)	46.8
	2011
	Total revenue from external customers	$	1,791		$	8,759		$	2,044		$	56		$	1,115		$	13,765
	Intersegment revenue	63			123			1,077			595			(1,858		)	—
	Total operating revenue	1,854			8,882			3,121			651			(743		)	13,765
	Depreciation, depletion and amortization	369			413			207			29			—			1,018
	Equity in earnings of equity method investees	—			3			23			9			—			35
	Interest income	10			65			27			71			(106		)	67
	Interest and related charges	183			148			57			514			(106		)	796
	Income taxes	264			655			323			(464		)	—			778
	Loss from discontinued operations, net of tax	—			—			—			(58		)	—			(58		)
	Net income (loss) attributable to Dominion	416			1,078			521			(607		)	—			1,408
	Capital expenditures	1,091			1,593			907			61			—			3,652
	(1) Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.
	(2) Segment information for 2012 and 2011 has been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.
Virginia Electric and Power Company	'
Segment Reporting Information [Line Items]	'
Segment Reporting Disclosure Other Information	'
	The following table presents segment information pertaining to Virginia Power's operations:
	Year Ended December 31,	DVP			Dominion			Corporate and			Adjustments &			Consolidated
					Generation			Other			Eliminations			Total
	(millions)
	2013
	Operating revenue	$	1,826		$	5,475		$	(6	)	$	—		$	7,295
	Depreciation and amortization	427			425			1			—			853
	Interest income	—			6			—			—			6
	Interest and related charges	175			192			2			—			369
	Income taxes	286			399			(26		)	—			659
	Net income (loss)	483			702			(47		)	—			1,138
	Capital expenditures	1,360			1,173			—			—			2,533
	Total assets (billions)	12			15.1			—			(0.1		)	27
	2012
	Operating revenue	$	1,847		$	5,379		$	—		$	—		$	7,226
	Depreciation and amortization	392			390			—			—			782
	Interest income	1			7			—			—			8
	Interest and related charges	186			199			—			—			385
	Income taxes	277			403			(27		)	—			653
	Net income (loss)	448			653			(51		)	—			1,050
	Capital expenditures	1,142			1,146			—			—			2,288
	Total assets (billions)	11.4			14.8			—			(1.4		)	24.8
	2011
	Operating revenue	$	1,793		$	5,546		$	(93	)	$	—		$	7,246
	Depreciation and amortization	368			350			—			—			718
	Interest income	10			8			—			—			18
	Interest and related charges	182			199			(50		)	—			331
	Income taxes	265			447			(172		)	—			540
	Net income (loss)	426			664			(268		)	—			822
	Capital expenditures	1,081			1,009			—			—			2,090

Quarterly_Financial_and_Common1

Quarterly Financial and Common Stock Data (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]	'
Quarterly Financial and Common Stock Data	'
		First			Second			Third			Fourth			Full Year
		Quarter			Quarter			Quarter			Quarter (2)
	(millions, except per share amounts)
	2013
	Operating revenue	$	3,523		$	2,980		$	3,432		$	3,185		$	13,120
	Income from operations	930			548			1,034			804			3,316
	Net income including noncontrolling interests	502			208			575			435			1,720
	Income from continuing operations(1)	494			272			592			431			1,789
	Income (loss) from discontinued operations(1)	1			(70		)	(23		)	—			(92		)
	Net income attributable to Dominion	495			202			569			431			1,697
	Basic EPS:
	Income from continuing operations(1)	0.86			0.47			1.02			0.74			3.09
	Income (loss) from discontinued operations(1)	—			(0.12		)	(0.04		)	—			(0.16		)
	Net income attributable to Dominion	0.86			0.35			0.98			0.74			2.93
	Diluted EPS:
	Income from continuing operations(1)	0.86			0.47			1.02			0.74			3.09
	Income (loss) from discontinued operations(1)	—			(0.12		)	(0.04		)	—			(0.16		)
	Net income attributable to Dominion	0.86			0.35			0.98			0.74			2.93
	Dividends declared per share	0.5625			0.5625			0.5625			0.5625			2.25
	Common stock prices (intraday high-low)	$58.25  -			$61.85  -			$64.04 - 55.51			$67.97  -			$67.97  -
		51.92			53.79						61.36			51.92
		First			Second			Third			Fourth			Full Year
		Quarter			Quarter			Quarter			Quarter
	2012
	Operating revenue	$	3,397		$	3,005		$	3,332		$	3,101		$	12,835
	Income from operations	918			628			551			761			2,858
	Net income (loss) including noncontrolling interests	501			265			215			(652		)	329
	Income from continuing operations(1)	504			290			261			372			1,427
	Income (loss) from discontinued operations(1)	(10		)	(32		)	(52		)	(1,031		)	(1,125		)
	Net income attributable to Dominion	494			258			209			(659		)	302
	Basic EPS:
	Income from continuing operations(1)	0.88			0.51			0.45			0.65			2.49
	Loss from discontinued operations(1)	(0.02		)	(0.06		)	(0.09		)	(1.80		)	(1.96		)
	Net income (loss) attributable to Dominion	0.86			0.45			0.36			(1.15		)	0.53
	Diluted EPS:
	Income from continuing operations(1)	0.88			0.51			0.45			0.64			2.49
	Loss from discontinued operations(1)	(0.02		)	(0.06		)	(0.09		)	(1.79		)	(1.96		)
	Net income (loss) attributable to Dominion	0.86			0.45			0.36			(1.15		)	0.53
	Dividends declared per share	0.5275			0.5275			0.5275			0.5275			2.11
	Common stock prices (intraday high-low)	$53.68  -			$54.69  -			$55.62 -			$53.89  -			$55.62  -
		48.87			49.87			52.15			48.94			48.87
	-1	Amounts attributable to Dominion's common shareholders.
	-2	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.
Virginia Electric and Power Company	'
Condensed Financial Statements, Captions [Line Items]	'
Quarterly Financial and Common Stock Data	'
	Virginia Power's quarterly results of operations were as follows:
		First			Second			Third			Fourth			Year
		Quarter			Quarter			Quarter			Quarter
	(millions)
	2013
	Operating revenue	$	1,781		$	1,710		$	2,059		$	1,745		$	7,295
	Income from operations	530			463			679			408			2,080
	Net income	287			265			387			199			1,138
	Balance available for common stock	283			261			383			194			1,121
	2012
	Operating revenue	$	1,754		$	1,756		$	2,086		$	1,630		$	7,226
	Income from operations	468			361			746			417			1,992
	Net income	243			172			415			220			1,050
	Balance available for common stock	239			168			411			216			1,034

Significant_Accounting_Policie3

Significant Accounting Policies (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounting Policy [Line Items]	'	'	'
Accrued unbilled revenue	$555	$411	'
Percentage of fuel currently subject to deferred fuel accounting	84.00%	'	'
Interest income	3	'	12
Reduction in interest expense	10	3	7
Income Tax Interest Income	'	8	'
Reduction in penalties (less than $1 million)	'	1	1
Accrued interest receivable	5	5	'
Interest and penalties payable	15	10	'
Income tax examination, penalties accrued	1	1	'
Accounts payable for checks outstanding	38	53	'
Margin assets	620	212	'
Margin liabilities	2	4	'
Capitalized interest costs	66	91	85
Inventory under LIFO method	7	24	'
Amount exceeded on LIFO basis	77	69	'
Virginia Electric and Power Company	'	'	'
Accounting Policy [Line Items]	'	'	'
Accrued unbilled revenue	395	348	'
Income Tax Interest Income	'	'	12
Income taxes payable	22	'	'
Noncurrent federal and state income taxes payable	28	36	'
Accounts payable for checks outstanding	21	30	'
Margin assets	11	18	'
Capitalized interest costs	33	31	31
AFUDC related to projects	32	37	20
State | Virginia Electric and Power Company	'	'	'
Accounting Policy [Line Items]	'	'	'
Income tax receivable	3	'	'
Non current income tax receivable	12	'	'
Federal | Virginia Electric and Power Company	'	'	'
Accounting Policy [Line Items]	'	'	'
Prepaid federal and state income taxes	'	$10	'

Significant_Accounting_Policie4

Significant Accounting Policies (Depreciation Rates and Estimated Useful Life) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Generation	'	'	'
Depreciation rates	2.71%	2.62%	2.68%
Generation | Virginia Electric and Power Company	'	'	'
Depreciation rates	2.71%	2.62%	2.68%
Transmission	'	'	'
Depreciation rates	2.36%	2.17%	2.26%
Transmission | Virginia Electric and Power Company	'	'	'
Depreciation rates	2.28%	1.98%	2.03%
Distribution	'	'	'
Depreciation rates	3.13%	3.17%	3.19%
Distribution | Virginia Electric and Power Company	'	'	'
Depreciation rates	3.33%	3.32%	3.33%
Storage	'	'	'
Depreciation rates	2.43%	2.59%	2.64%
Gas gathering and processing	'	'	'
Depreciation rates	2.39%	2.49%	2.52%
General and other	'	'	'
Depreciation rates	3.82%	4.55%	4.66%
General and other | Virginia Electric and Power Company	'	'	'
Depreciation rates	3.51%	4.32%	4.38%
Merchant generation-nuclear	'	'	'
Property, Plant and Equipment, Useful Life	'44 years	'	'
Minimum | General and other	'	'	'
Property, Plant and Equipment, Useful Life	'5 years	'	'
Minimum | Merchant generation-other	'	'	'
Property, Plant and Equipment, Useful Life	'15 years	'	'
Maximum | General and other	'	'	'
Property, Plant and Equipment, Useful Life	'59 years	'	'
Maximum | Merchant generation-other	'	'	'
Property, Plant and Equipment, Useful Life	'36 years	'	'

Dispositions_Narrative_Details

Dispositions (Narrative) (Details) (USD $)	12 Months Ended		1 Months Ended	6 Months Ended	12 Months Ended		1 Months Ended		1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2013	Jun. 30, 2013	Dec. 31, 2013	Dec. 31, 2013	Aug. 31, 2013	Dec. 31, 2013	Aug. 31, 2013
			Illinois Gas Contracts	Brayton Point and Kincaid	Brayton Point and Kincaid	Loss from Discontinued Operations	Elwood	Elwood	Elwood
						Brayton Point and Kincaid			Other Income
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'	'	'
Sales price	'	'	$32	'	'	'	'	'	'
Gain on sale	'	'	29	'	'	'	'	'	'
After-tax gain on sale	'	'	18	'	'	'	'	'	'
Asset disposition adjustment	44	11	3	'	'	16	'	'	'
Impairment charge	1,600	'	'	48	1,600	'	'	'	'
Long-lived assets impairment charges, net of tax	'	'	'	28	'	'	'	'	'
Ownership percentage	'	'	'	'	'	'	'	50.00%	'
Proceeds from sale of equity method investment	'	'	'	'	'	'	465	'	'
Gain on sale of investment	'	'	'	'	'	'	'	'	35
After tax gain on sale of investment	'	'	'	'	'	'	'	'	25
Loss from discontinued operation	'	'	'	'	-17	'	'	'	'
Loss on discontinued operation, net of tax	'	'	'	'	($18)	'	'	'	'

Dispositions_Schedule_of_Dispo

Dispositions (Schedule of Disposal Groups, Including Discontinued Operations, Income Statement) (Details) (USD $)	6 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'		'		'
Impairment charge	'	$1,600		'		'
Brayton Point and Kincaid	'	'		'		'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'		'		'
Operating revenue	'	304		258		380
Loss before income taxes	'	-135	[1]	-1,768	[2]	-57
Charges related to early redemption of debt	'	-64		'		'
Impairment charge	48	1,600		'		'
State Line and Salem Harbor	'	'		'		'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'		'		'
Operating revenue	'	'		57		233
Loss before income taxes	'	'		-49		-34
Impairment charge	'	'		'		$55
[1]	Includes $64 million of charges related to the defeasance of Brayton Point debt and the early redemption of Kincaid debt in 2013. See Note 17 for more information.
[2]	Includes a long-lived asset impairment charge of $1.6 billion.

Operating_Revenue_Operating_Re

Operating Revenue (Operating Revenue) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Electric sales:

'

'

'

'

'

'

'

'

'

'

'

Regulated

'

'

'

'

'

'

'

'

$7,193

$7,102

$7,114

Nonregulated

'

'

'

'

'

'

'

'

2,511

2,483

2,721

Gas sales:

'

'

'

'

'

'

'

'

'

'

'

Regulated

'

'

'

'

'

'

'

'

323

250

287

Nonregulated

'

'

'

'

'

'

'

'

930

1,071

1,634

Gas transportation and storage

'

'

'

'

'

'

'

'

1,535

1,401

1,506

Other

'

'

'

'

'

'

'

'

628

528

503

Total operating revenue

3,185

[1]

3,432

2,980

3,523

3,101

3,332

3,005

3,397

13,120

12,835

[2]

13,765

[2]

Virginia Electric and Power Company

'

'

'

'

'

'

'

'

'

'

'

Electric sales:

'

'

'

'

'

'

'

'

'

'

'

Regulated

'

'

'

'

'

'

'

'

7,193

7,102

7,114

Gas sales:

'

'

'

'

'

'

'

'

'

'

'

Other

'

'

'

'

'

'

'

'

102

124

132

Total operating revenue

$1,745

$2,059

$1,710

$1,781

$1,630

$2,086

$1,756

$1,754

$7,295

$7,226

$7,246

[1]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.

[2]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Loss Carryforwards [Line Items]	'	'	'
Deferred tax liabilities classified as current representing cumulative adjustments from tax accounting method changes	$17	'	'
Operating loss carryforward	'	195	51
Unrecognized tax benefits that would impact effective tax rate	126	167	184
Change in unrecognized tax benefits	29	1	-51
Decrease of unrecognized tax benefits	2	4	0
Federal	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Operating loss carryforward	1,200	'	'
Investment tax credit	58	'	'
Tax credits	45	'	'
Payment after conclusion of audit	46	'	'
Federal | Scenario, Forecast	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Decrease of unrecognized tax benefits	115	'	'
Earnings increase as a result of tax settlement	65	'	'
State	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Operating loss carryforward	1,500	'	'
Carryforwards valuation allowance	763	'	'
General Business | State	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Tax credits	133	'	'
Investment Credit That Expires In 2014 | State	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Tax credits	7	'	'
Fairless | State	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Reduction of valuation allowance	'	20	'
Virginia Electric and Power Company	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Unrecognized tax benefits that would impact effective tax rate	8	13	20
Change in unrecognized tax benefits	-4	-1	-6
Decrease of unrecognized tax benefits	2	4	0
Virginia Electric and Power Company | Federal	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Operating loss carryforward	282	'	'
Tax credits	5	'	'
Virginia Electric and Power Company | Federal | Scenario, Forecast	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Decrease of unrecognized tax benefits	25	'	'
Earnings increase as a result of tax settlement	7	'	'
Virginia Electric and Power Company | State	'	'	'
Operating Loss Carryforwards [Line Items]	'	'	'
Operating loss carryforward	$2	'	'

Income_Taxes_Income_Tax_Expens

Income Taxes (Income Tax Expense for Continuing Operations Including Noncontrolling Interests) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Current:	'		'		'
Federal	$317	[1]	$43	[1]	$31	[1]
State	110	[1]	84	[1]	16	[1]
Total current expense	427	[1]	127	[1]	47	[1]
Deferred:	'		'		'
Federal	497	[1]	645	[1]	685	[1]
State	-31	[1]	40	[1]	48	[1]
Total deferred expense	466	[1]	685	[1]	733	[1]
Amortization of deferred investment tax credits	-1	[1]	-1	[1]	-2	[1]
Total income tax expense	892	[1]	811	[1],[2]	778	[1],[2]
Operating loss carryforward	'		195		51
Tax benefit recognized	'		'		346
Virginia Electric and Power Company	'		'		'
Current:	'		'		'
Federal	357	[3]	70	[3]	-35	[3]
State	62	[3]	81	[3]	79	[3]
Total current expense	419	[3]	151	[3]	44	[3]
Deferred:	'		'		'
Federal	224	[3]	482	[3]	484	[3]
State	17	[3]	21	[3]	13	[3]
Total deferred expense	241	[3]	503	[3]	497	[3]
Amortization of deferred investment tax credits	-1	[3]	-1	[3]	-1	[3]
Total income tax expense	659	[3]	653	[3]	540	[3]
Tax benefit recognized	'		'		$54
[1]	In 2012, Dominion’s current federal income tax expense for continuing and discontinued operations includes a $195 million benefit related to a carryback of its 2012 net operating loss. In 2011, Dominion’s deferred federal income tax expense includes the recognition of a $346 million benefit, including $51 million related to discontinued operations, for its 2011 net operating loss expected to be used to reduce taxable income in future years.
[2]	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.
[3]	In 2011, Virginia Power’s deferred federal income tax expense includes a $54 million benefit related to a portion of its 2011 net operating loss that is expected to be used in future years. Also, Virginia Power’s current federal income tax expense reflects the amounts of its 2011 net operating losses realized through its participation in a tax sharing agreement with Dominion and its subsidiaries.

Income_Taxes_Reconciliation_of

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)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Contingency [Line Items]	'	'	'
U.S. statutory rate	35.00%	35.00%	35.00%
Increases (reductions) resulting from:	'	'	'
State taxes, net of federal benefit	2.10%	4.20%	1.90%
Valuation allowances	-0.10%	-0.70%	0.00%
Investment and production tax credits	-2.40%	-0.50%	-0.60%
AFUDC - equity	-0.60%	-0.90%	-0.60%
Employee stock ownership plan deduction	-0.60%	-0.70%	-0.60%
Other, net	-0.40%	-0.60%	-0.70%
Effective tax rate	33.00%	35.80%	34.40%
Virginia Electric and Power Company	'	'	'
Income Tax Contingency [Line Items]	'	'	'
U.S. statutory rate	35.00%	35.00%	35.00%
Increases (reductions) resulting from:	'	'	'
State taxes, net of federal benefit	3.10%	3.90%	4.40%
Valuation allowances	0.00%	0.00%	0.00%
Investment and production tax credits	-0.20%	0.00%	0.00%
AFUDC - equity	-0.80%	-0.90%	-0.80%
Employee stock ownership plan deduction	0.00%	0.00%	0.00%
Other, net	-0.40%	0.30%	1.10%
Effective tax rate	36.70%	38.30%	39.70%

Income_Taxes_The_Companies_Def

Income Taxes (The Companies Deferred Income Taxes Components) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Income Tax Contingency [Line Items]	'	'
Total deferred income tax assets	$2,142	$2,505
Total deferred income tax liabilities	8,463	7,716
Total deferred income taxes:	'	'
Plant and equipment, primarily depreciation method and basis differences	5,383	4,601
Nuclear decommissioning	1,136	994
Deferred state income taxes	606	474
Federal benefit of deferred state income taxes	-212	-166
Deferred fuel, purchased energy and gas costs	-33	3
Pension benefits	435	231
Other postretirement benefits	-78	-171
Loss and credit carryforwards	-797	-656
Valuation allowances	69	93
Partnership basis differences	125	174
Other	-313	-366
Total net deferred income tax liabilities	6,321	5,211
Virginia Electric and Power Company	'	'
Income Tax Contingency [Line Items]	'	'
Total deferred income tax assets	462	466
Total deferred income tax liabilities	4,498	4,238
Total deferred income taxes:	'	'
Plant and equipment, primarily depreciation method and basis differences	3,628	3,394
Nuclear decommissioning	441	407
Deferred state income taxes	285	265
Federal benefit of deferred state income taxes	-100	-93
Deferred fuel, purchased energy and gas costs	-50	-16
Pension benefits	-52	-17
Other postretirement benefits	-3	-7
Loss and credit carryforwards	-106	-77
Valuation allowances	0	0
Partnership basis differences	0	0
Other	-7	-84
Total net deferred income tax liabilities	$4,036	$3,772

Income_Taxes_Unrecognized_Tax_

Income Taxes (Unrecognized Tax Benefits) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'	'
Balance at January 1	$293	$347	$307
Increases-prior period positions	17	28	127
Decreases-prior period positions	-99	-106	-119
Increases-current period positions	30	43	64
Decreases-current period positions	-5	0	-21
Settlements with tax authorities	-2	-4	0
Expiration of statutes of limitations	-12	-15	-11
Balance at December 31	222	293	347
Virginia Electric and Power Company	'	'	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'	'
Balance at January 1	57	114	117
Increases-prior period positions	12	4	22
Decreases-prior period positions	-42	-80	-51
Increases-current period positions	14	24	47
Decreases-current period positions	0	0	-21
Settlements with tax authorities	-2	-4	0
Expiration of statutes of limitations	0	-1	0
Balance at December 31	$39	$57	$114

Income_Taxes_Earliest_Tax_Year

Income Taxes (Earliest Tax Year) (Details)	12 Months Ended
	Dec. 31, 2013
Pennsylvania	'
Operation In Major Geographical Areas Tax Year [Line Items]	'
Earliest Open Tax Year	'2010
Connecticut	'
Operation In Major Geographical Areas Tax Year [Line Items]	'
Earliest Open Tax Year	'2010
Massachusetts	'
Operation In Major Geographical Areas Tax Year [Line Items]	'
Earliest Open Tax Year	'2008
Virginia	'
Operation In Major Geographical Areas Tax Year [Line Items]	'
Earliest Open Tax Year	'2010	[1]
West Virginia	'
Operation In Major Geographical Areas Tax Year [Line Items]	'
Earliest Open Tax Year	'2010
[1]	Virginia is the only state considered major for Virginia Power's operations.

Income_Taxes_Income_Taxes_Sche

Income Taxes Income Taxes (Schedule of Income Tax Expense from Discontinued Operations) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current:	'	'	'
Federal	($274)	($248)	($41)
State	-41	-6	-17
Total current benefit	-315	-254	-58
Deferred:	'	'	'
Federal	232	-368	10
State	40	-70	15
Total deferred expense (benefit)	272	-438	25
Total income tax benefit	($43)	($692)	($33)

Fair_Value_Measurements_Narrat

Fair Value Measurements (Narrative) (Details) (USD $)

12 Months Ended

3 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2013

Jun. 30, 2012

Dec. 31, 2013

Sep. 30, 2012

Mar. 31, 2011

Sep. 30, 2011

Sep. 30, 2011

Sep. 30, 2011

Sep. 30, 2011

Mar. 31, 2011

Dec. 31, 2012

Dec. 31, 2012

Jun. 30, 2013

Dec. 31, 2013

Kewaunee

Salem Harbor

Elwood

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Fair Value, Measurements, Nonrecurring

Gas, Transmission and Distribution Equipment

Gas, Transmission and Distribution Equipment

Utility

Kewaunee

State Line

Emissions allowances

Emissions allowances

Emissions allowances

Emissions allowances

Maximum

Brayton Point

Brayton Point

Fair Value, Measurements, Nonrecurring

Operating Expense

Operating Expense

Loss from Discontinued Operations

Virginia Electric and Power Company

State Line

Level 2

Level 3

Operating Expense

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment charge

'

'

'

'

'

'

'

'

'

'

'

'

'

$49

'

Impairment charge after tax

'

'

'

'

'

'

'

'

'

'

'

'

'

29

'

Estimated fair value

'

'

'

'

'

'

'

'

'

'

1

'

'

'

1

Ownership percentage

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

Impairment charge

1,600

'

'

'

378

'

'

'

'

'

'

1,600

'

'

'

Impairment and other charges, net of tax

'

'

'

'

281

'

'

'

'

'

'

1,000

'

'

'

Long lived assets estimated fair value

'

'

'

'

'

'

'

'

'

'

'

'

216

'

'

Number of utilities

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Impairment and other charges

'

'

'

'

435

'

'

'

'

'

'

'

'

'

'

Long-lived assets impairment charges, net of tax

'

'

'

'

244

'

'

'

'

'

'

'

'

'

'

Inventory write-down

'

'

'

'

33

'

'

'

'

'

'

'

'

'

'

Inventory write down, net of tax

'

'

'

'

21

'

'

'

'

'

'

'

'

'

'

Severance costs

'

'

'

'

24

'

'

'

'

'

'

'

'

'

'

Severance costs net of tax

'

'

'

'

16

'

'

'

'

'

'

'

'

'

'

Impairment charge

'

'

'

'

'

55

'

'

'

'

'

'

'

'

'

Impairment charge, net of tax

'

'

'

'

'

39

'

'

'

'

'

'

'

'

'

After tax charge on disposal of assets

'

'

27

'

'

'

'

'

'

'

'

'

'

'

'

Pretax charge on disposal of assets

'

'

16

'

'

'

'

'

'

'

'

'

'

'

'

So2 emissions allowances obtained for arp cnd cair compliance

'

'

'

'

'

'

'

57

'

43

'

'

'

'

'

Salem Harbor, impairment charge

'

'

'

'

'

'

14

57

43

43

'

'

'

'

'

Impairment of intangible assets after tax

'

'

'

'

'

'

$8

$34

$26

$26

'

'

'

'

'

Fair_Value_Measurements_Fair_V

Fair Value Measurements (Fair Value, Option, Quantitative Disclosures) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Gas

Gas

FTRs

Liquids

Electricity

Electricity

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Assets

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Fair Value, Option, Quantitative Disclosures, Liabilities

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Full Requirements Contracts:

Minimum

Minimum

Minimum

Minimum

Minimum

Weighted Average

Weighted Average

Weighted Average

Weighted Average

Weighted Average

Maximum

Maximum

Maximum

Maximum

Maximum

Minimum

Minimum

Minimum

Minimum

Minimum

Weighted Average

Weighted Average

Weighted Average

Weighted Average

Weighted Average

Weighted Average

Maximum

Maximum

Maximum

Maximum

Maximum

Gas

Gas

FTRs

Liquids

Electricity

Gas

Gas

FTRs

Liquids

Electricity

Gas

Gas

FTRs

Liquids

Electricity

Gas

Gas

FTRs

Liquids

Electricity

Gas

Gas

Gas

FTRs

Liquids

Electricity

Gas

Gas

FTRs

Liquids

Electricity

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Full Requirements Contracts:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Full Requirements Contracts:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Full Requirements Contracts:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Options:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Physical and Financial Forwards and Futures:

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative assets

$890,000,000

[1]

$828,000,000

[1]

$32,000,000

$14,000,000

[2]

$4,000,000

[2]

$2,000,000

[3]

$6,000,000

[4]

'

$6,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative liabilities

1,102,000,000

[5]

661,000,000

[5]

48,000,000

19,000,000

[2]

8,000,000

[2]

9,000,000

[3]

11,000,000

[4]

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Market Price

'

'

'

'

'

'

'

'

'

-2

[6]

3

[6]

-1

[6]

1

[6]

10

[6]

2

[6]

4

[6]

0

[6]

1

[6]

42

[6],[7]

5

[6]

5

[6]

5

[6]

3

[6]

406

[6]

-2

[6]

3

[6]

-1

[6]

1

[6]

28

[6]

1

[6]

'

7

[6]

1

[6]

1

[6]

39

[6]

30

[6]

11

[6]

5

[6]

3

[6]

240

[6]

Price Volatility

'

'

'

'

'

'

'

'

'

'

14.00%

[8]

'

'

'

'

20.00%

[8]

'

'

'

'

36.00%

[8]

'

'

'

'

14.00%

[8]

'

'

'

'

'

20.00%

[8]

'

'

'

'

36.00%

[8]

'

'

'

Price Correlation

'

'

'

'

'

'

'

'

'

'

-9.00%

[9]

'

'

'

'

36.00%

[9]

'

'

'

'

100.00%

[9]

'

'

'

'

-9.00%

[9]

'

'

'

'

'

36.00%

[9]

'

'

'

'

100.00%

[9]

'

'

'

Mean Reversion

'

'

'

'

'

'

'

'

'

'

$0.01

[10]

'

'

'

'

$1

[10]

'

'

'

'

$1

[10]

'

'

'

'

$0.01

[11]

'

'

'

'

$1

[11]

'

'

'

'

'

$1

[11]

'

'

'

Load Shaping

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

[12]

'

'

'

'

7.00%

[12]

'

'

'

'

10.00%

[12]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Usage Factor

'

'

'

'

'

'

'

'

'

'

'

'

'

11.00%

[11]

'

'

'

'

16.00%

[11]

'

'

'

'

29.00%

[11]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

At December 31, 2013, the total derivative asset balance contains $687 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $203 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.

[2]

Includes basis.

[3]

Information represents Virginia Power's quantitative information about Level 3 fair value measurements.

[4]

Includes NGLs.

[5]

At December 31, 2013, the total derivative liability balance contains $828 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $274 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.

[6]

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

[7]

The range in market prices is the result of large variability in hourly power prices during peak and off-peak hours.

[8]

Represents volatilities unrepresented in published markets.

[9]

Represents intra-price correlations for which markets do not exist.

[10]

Represents mean-reverting property in price simulation modeling.

[11]

Represents expected increase (decrease) in sales volumes compared to historical usage.

[12]

Converts block monthly loads to 24-hour load shapes.

Fair_Value_Measurements_Assets

Fair Value Measurements (Assets and Liabilities that are Measured at Fair Value on a Recurring Basis) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	$890	[1]	$828	[1]
Derivative liabilities	1,102	[2]	661	[2]
Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	32		'
Derivative liabilities	48		'
Fair Value, Measurements, Recurring	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	4,791		4,175
Total liabilities	1,102		661
Fair Value, Measurements, Recurring | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	753		735
Derivative liabilities	1,102		595
Fair Value, Measurements, Recurring | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	137		93
Derivative liabilities	'		66
Fair Value, Measurements, Recurring | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	2,417	[3]	1,973	[3]
Fair Value, Measurements, Recurring | Equity securities: | Large Cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	13	[3]	12	[3]
Fair Value, Measurements, Recurring | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	79	[3]	59	[3]
Fair Value, Measurements, Recurring | Fixed Income: | Corporate debt instruments	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	345	[3]	325	[3]
Fair Value, Measurements, Recurring | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	590	[3]	543	[3]
Fair Value, Measurements, Recurring | Fixed Income: | State and municipal	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	343	[3]	315	[3]
Fair Value, Measurements, Recurring | Fixed Income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	3	[3]	7	[3]
Fair Value, Measurements, Recurring | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	103	[3]	80	[3]
Fair Value, Measurements, Recurring | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	8	[3]	33	[3]
Fair Value, Measurements, Recurring | Level 1	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	2,927		2,460
Total liabilities	3		8
Fair Value, Measurements, Recurring | Level 1 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	3		12
Derivative liabilities	3		8
Fair Value, Measurements, Recurring | Level 1 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	0		0
Derivative liabilities	'		0
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	2,417	[3]	1,973	[3]
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large Cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	13	[3]	12	[3]
Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	79	[3]	59	[3]
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	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	415	[3]	391	[3]
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	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 1 | Fixed Income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 1 | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	13	[3]
Fair Value, Measurements, Recurring | Level 1 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 2	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	1,832		1,631
Total liabilities	1,051		594
Fair Value, Measurements, Recurring | Level 2 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	718		639
Derivative liabilities	1,051		528
Fair Value, Measurements, Recurring | Level 2 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	137		93
Derivative liabilities	'		66
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large Cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	345	[3]	325	[3]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	175	[3]	152	[3]
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	343	[3]	315	[3]
Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	3	[3]	7	[3]
Fair Value, Measurements, Recurring | Level 2 | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	103	[3]	67	[3]
Fair Value, Measurements, Recurring | Level 2 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	8	[3]	33	[3]
Fair Value, Measurements, Recurring | Level 3	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	32		84
Total liabilities	48		59
Fair Value, Measurements, Recurring | Level 3 | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	32		84
Derivative liabilities	48		59
Fair Value, Measurements, Recurring | Level 3 | Interest rate	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	0		0
Derivative liabilities	'		0
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large Cap | Non-U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | Other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Cash equivalents and other	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Fair Value, Measurements, Recurring | Level 3 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	53	[1]	6	[1]
Derivative liabilities	12	[2]	34	[2]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Total assets	1,716		1,409
Total liabilities	12		34
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Commodity	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Derivative assets	5		6
Derivative liabilities	12		9
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 assets	48		'
Derivative liabilities	'		25
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	1,021	[3]	779	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	36	[3]	27	[3]
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	191	[3]	196	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	212	[3]	234	[3]
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	164	[3]	118	[3]
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	'		1	[3]
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	31	[3]	38	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	8	[3]	10	[3]
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	1,203		981
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 assets	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 assets	0		'
Derivative liabilities	'		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	1,021	[3]	779	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	36	[3]	27	[3]
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	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	146	[3]	168	[3]
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	0	[3]	0	[3]
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	'		0	[3]
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	0	[3]	7	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 1 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	511		423
Total liabilities	3		31
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 assets	3		1
Derivative liabilities	3		6
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 assets	48		'
Derivative liabilities	'		25
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	191	[3]	196	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	66	[3]	66	[3]
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	164	[3]	118	[3]
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	'		1	[3]
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	31	[3]	31	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 2 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	8	[3]	10	[3]
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		5
Total liabilities	9		3
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 assets	2		5
Derivative liabilities	9		3
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 assets	0		'
Derivative liabilities	'		0
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Large Cap | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Equity securities: | Other | U.S.:	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	0	[3]	0	[3]
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	0	[3]	0	[3]
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	'		0	[3]
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	0	[3]	0	[3]
Virginia Electric and Power Company | Fair Value, Measurements, Recurring | Level 3 | Restricted cash equivalents	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Investments	$0	[3]	$0	[3]
[1]	At December 31, 2013, the total derivative asset balance contains $687 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $203 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.
[2]	At December 31, 2013, the total derivative liability balance contains $828 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $274 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.
[3]	Includes investments held in the nuclear decommissioning and rabbi trusts.

Fair_Value_Measurements_Net_Ch

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 $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]	'	'	'
Included in earnings	($9)	($15)	($77)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	0	42	22
Commodity | Level 3	'	'	'
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]	'	'	'
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	0	42	22
Commodity | Level 3 | Fair Value, Measurements, Recurring	'	'	'
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]	'	'	'
Beginnning balance	25	-71	-50
Included in earnings	-9	-15	-77
Included in other comprehensive income (loss)	1	101	14
Included in regulatory assets/liabilities	-9	30	-42
Settlements	-23	47	88
Transfers out of Level 3	-1	-67	-4
Ending balance	-16	25	-71
Commodity | Virginia Electric and Power Company | Level 3 | Fair Value, Measurements, Recurring	'	'	'
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation Calculation [Roll Forward]	'	'	'
Beginnning balance	2	-28	14
Included in earnings	-17	-50	-45
Included in regulatory assets/liabilities	-9	30	-42
Settlements	17	50	45
Ending balance	($7)	$2	($28)

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Gains and Losses Included in the Level 3 Fair Value Category) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Total gains (losses) included in earnings	($9)	($15)	($77)
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	0	42	22
Operating Revenue	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Total gains (losses) included in earnings	11	35	-32
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	1	42	22
Electric Fuel and Energy Purchases	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Total gains (losses) included in earnings	-19	-50	-45
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	0	0	0
Purchased Gas	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'
Total gains (losses) included in earnings	-1	0	0
The amount of total gains (losses) for the period included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at the reporting date	($1)	$0	$0

Fair_Value_Measurements_Financ

Fair Value Measurements (Financial Instruments' Carrying Amounts and Fair Values) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, including securities due within one year	$20,842		'
Subsidiary preferred stock	257		257
Valuation of certain fair value hedges	55		93
Deferred issuance expenses	2		2
Carrying Amount	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, including securities due within one year	18,396	[1]	16,841	[1]
Long-term debt - VIEs	0	[2]	860	[2]
Junior subordinated notes	1,373	[2]	1,373	[2]
Remarketable subordinated notes	1,080	[2]	0	[2]
Subsidiary preferred stock	257	[3]	257	[3]
Estimated Fair Value	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, including securities due within one year	19,887	[1],[4]	19,898	[1],[4]
Long-term debt - VIEs	0	[2],[4]	864	[2],[4]
Junior subordinated notes	1,394	[2],[4]	1,430	[2],[4]
Remarketable subordinated notes	1,192	[2],[4]	0	[2],[4]
Subsidiary preferred stock	261	[3],[4]	255	[3],[4]
Virginia Electric and Power Company	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, including securities due within one year	8,043		'
Subsidiary preferred stock	257		257
Virginia Electric and Power Company | Carrying Amount	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, including securities due within one year	8,032	[1]	6,669	[1]
Subsidiary preferred stock	257	[3]	257	[3]
Virginia Electric and Power Company | Estimated Fair Value	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, including securities due within one year	8,897	[1],[4]	8,270	[1],[4]
Subsidiary preferred stock	$261	[3],[4]	$255	[3],[4]
[1]	Carrying amount includes amounts which represent the unamortized discount and premium. At December 31, 2013, and 2012, includes the valuation of certain fair value hedges associated with Dominion's fixed rate debt, of approximately $55 million and $93 million, respectively.
[2]	Carrying amount includes amounts which represent the unamortized discount or premium.
[3]	Includes deferred issuance expenses of $2 million at December 31, 2013 and 2012.
[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.

Derivatives_and_Hedge_Accounti2

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Assets) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	$883		$799
Total derivatives, not subject to a master netting or similar arrangement	7		29
Derivative Asset	890	[1]	828	[1]
Gross Amounts Offset in the Consolidated Balance Sheet	0	[1]	0	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	568		466
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		4
Net Amounts	315		329
Derivative assets, current	687		518
Derivative assets, noncurrent	620		212
Current Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets, current	687		'
Non Current Derivative Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets, noncurrent	203		310
Current Derivative Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets, current	'		518
Interest rate | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	137		93
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0		19
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	137		74
Commodity | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	240		290
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	63		97
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	177		193
Commodity | Exchange	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	506		416
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	505		350
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		4
Net Amounts	1		62
Virginia Electric and Power Company	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	53		6
Total derivatives, not subject to a master netting or similar arrangement	0		0
Derivative Asset	53	[1]	6	[1]
Gross Amounts Offset in the Consolidated Balance Sheet	0	[1]	0	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4		3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	49		3
Derivative assets, noncurrent	11		18
Virginia Electric and Power Company | Current Assets	'		'
Offsetting Assets [Line Items]	'		'
Derivative assets, current	53		6
Virginia Electric and Power Company | Interest rate | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	48		0
Gross Amounts Offset in the Consolidated Balance Sheet	0		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 Received	0		0
Net Amounts	48		0
Virginia Electric and Power Company | Commodity | Over-the-counter	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	4		6
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4		3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		0
Net Amounts	0		3
Virginia Electric and Power Company | Commodity | Exchange	'		'
Offsetting Assets [Line Items]	'		'
Gross Amounts of Recognized Assets	1		'
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0		'
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Received	0		'
Net Amounts	$1		'
[1]	At December 31, 2013, the total derivative asset balance contains $687 million of current assets, which is presented in current derivative assets, in Dominion’s Consolidated Balance Sheet, and $203 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative asset balance contains $518 million of current assets, which is presented in current derivative assets in Dominion’s Consolidated Balance Sheet and $310 million of noncurrent assets, which is presented in other deferred charges and other assets in Dominion’s Consolidated Balance Sheet.

Derivatives_and_Hedge_Accounti3

Derivatives and Hedge Accounting Activities (Schedule of Offsetting Liabilities) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	$1,100		$650
Gross Amounts Offset in the Consolidated Balance Sheet	0	[1]	0	[1]
Total derivatives, not subject to a master netting or similar arrangement	2		11
Derivative liabilities	1,102	[1]	661	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	568		466
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	402		63
Net Amounts	130		121
Derivative liabilities	828		510
Derivative Liability, Noncurrent	2		4
Current Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative liabilities	828		510
Non Current Derivative Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative Liability, Noncurrent	274		151
Interest rate | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	0		66
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	0		19
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	0		0
Net Amounts	0		47
Commodity | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	262		191
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	63		97
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	69		20
Net Amounts	130		74
Commodity | Exchange	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	838		393
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	505		350
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	333		43
Net Amounts	0		0
Virginia Electric and Power Company	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	12		34
Gross Amounts Offset in the Consolidated Balance Sheet	0	[1]	0	[1]
Total derivatives, not subject to a master netting or similar arrangement	0		0
Derivative liabilities	12	[1]	34	[1]
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4		3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	7		2
Net Amounts	1		29
Derivative liabilities	12		33
Virginia Electric and Power Company | Current Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative liabilities	12		33
Virginia Electric and Power Company | Non Current Derivative Liabilities	'		'
Offsetting Liabilities [Line Items]	'		'
Derivative Liability, Noncurrent	'		1
Virginia Electric and Power Company | Interest rate | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	0		25
Gross Amounts Offset in the Consolidated Balance Sheet	0		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 Paid	0		0
Net Amounts	0		25
Virginia Electric and Power Company | Commodity | Over-the-counter	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	12		7
Gross Amounts Offset in the Consolidated Balance Sheet	0		0
Gross Amounts Not Offset in the Consolidated Balance Sheet, Financial Instruments	4		3
Gross Amounts Not Offset in the Consolidated Balance Sheet, Cash Collateral Paid	7		0
Net Amounts	1		4
Virginia Electric and Power Company | Commodity | Exchange	'		'
Offsetting Liabilities [Line Items]	'		'
Gross Amounts of Recognized Liabilities	0		2
Gross Amounts Offset in the Consolidated Balance Sheet	0		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 Paid	0		2
Net Amounts	$0		$0
[1]	At December 31, 2013, the total derivative liability balance contains $828 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet, and $274 million of noncurrent liabilities, which is presented in the other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet. At December 31, 2012, the total derivative liability balance contains $510 million of current liabilities, which is presented in current derivative liabilities in Dominion’s Consolidated Balance Sheet and $151 million of noncurrent liabilities, which is presented in other deferred credits and other liabilities in Dominion’s Consolidated Balance Sheet.

Derivatives_and_Hedge_Accounti4

Derivatives and Hedge Accounting Activities (Volume of our Derivative Activity) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Current	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	$2,050
Current | Natural Gas (bcf): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	116,000,000,000	[1]
Current | Natural Gas (bcf): | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	466,000,000,000	[1]
Current | Electricity (MWh): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	14,814,767	[1]
Current | Electricity (MWh): | FTRs	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	41,316,345
Current | Capacity (MW)	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity of Electricity (in Megawatts)	83,050
Current | Liquids (gallons)	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	151,200,000	[2]
Noncurrent	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	750
Noncurrent | Natural Gas (bcf): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	19,000,000,000	[1]
Noncurrent | Natural Gas (bcf): | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	281,000,000,000	[1]
Noncurrent | Electricity (MWh): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	14,935,144	[1]
Noncurrent | Electricity (MWh): | FTRs	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	437,384
Noncurrent | Capacity (MW)	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity of Electricity (in Megawatts)	18,300
Noncurrent | Liquids (gallons)	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	0	[2]
Virginia Electric and Power Company | Current	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	600
Virginia Electric and Power Company | Current | Natural Gas (bcf): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	15,000,000,000
Virginia Electric and Power Company | Current | Natural Gas (bcf): | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	7,000,000,000
Virginia Electric and Power Company | Current | Electricity (MWh): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	624,800
Virginia Electric and Power Company | Current | Electricity (MWh): | FTRs	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	39,186,609
Virginia Electric and Power Company | Current | Capacity (MW)	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity of Electricity (in Megawatts)	75,500
Virginia Electric and Power Company | Noncurrent	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Interest rate	$0
Virginia Electric and Power Company | Noncurrent | Natural Gas (bcf): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	0
Virginia Electric and Power Company | Noncurrent | Natural Gas (bcf): | Basis	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of natural gas (in billion cubic feet and gallons)	0
Virginia Electric and Power Company | Noncurrent | Electricity (MWh): | Fixed Price	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	0
Virginia Electric and Power Company | Noncurrent | Electricity (MWh): | FTRs	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Volume of electricity (in Megawatt hours)	0
Virginia Electric and Power Company | Noncurrent | Capacity (MW)	'
Derivative Instruments, Gain (Loss) [Line Items]	'
Capacity of Electricity (in Megawatts)	18,300
[1]	Includes options.
[2]	Includes NGLs and oil.

Derivatives_and_Hedge_Accounti5

Derivatives and Hedge Accounting Activities (Selected Information Related to Gains (Losses) on Cash Flow Hedges Included in AOCI) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
In Millions, unless otherwise specified			Commodity	Commodity	Commodity	Interest rate
			Gas	Electricity	Other
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'	'	'
AOCI After-Tax	($288)	($122)	($3)	($172)	($3)	($110)
Amounts Expected to be Reclassified to Earnings during the next 12 Months After-Tax	($137)	'	($3)	($124)	($3)	($7)
Maximum Term	'	'	'28 months	'36 months	'29 months	'364 months

Derivatives_and_Hedge_Accounti6

Derivatives and Hedge Accounting Activities (Fair Values of our Derivatives) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	$890		$828
Total Fair Value, Liabilities	1,102		661
Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	687		518
Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	571		482
Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	116		36
Noncurrent Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	203	[1]	310	[1]
Noncurrent Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	182		253
Noncurrent Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	21		57
Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	828		510
Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	828		444
Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		66
Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	274	[2]	151	[2]
Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	274		151
Fair Value - Derivatives under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	214		326
Total Fair Value, Liabilities	386		227
Fair Value - Derivatives under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	165		139
Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	49		103
Fair Value - Derivatives under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	116		36
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	49	[1]	187	[1]
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	28		130
Fair Value - Derivatives under Hedge Accounting | Noncurrent Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	21		57
Fair Value - Derivatives under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	267		169
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	267		103
Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		66
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	119	[2]	58	[2]
Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	119		58
Fair Value - Derivatives not under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	676		502
Total Fair Value, Liabilities	716		434
Fair Value - Derivatives not under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	522		379
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	522		379
Fair Value - Derivatives not under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	0		0
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	154	[1]	123	[1]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	154		123
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	0		0
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	561		341
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	561		341
Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		0
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	155	[2]	93	[2]
Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	155		93
Virginia Electric and Power Company	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	53		6
Total Fair Value, Liabilities	12		34
Virginia Electric and Power Company | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	53	[3]	6	[3]
Virginia Electric and Power Company | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	5		6
Virginia Electric and Power Company | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	48		'
Virginia Electric and Power Company | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	12		33
Virginia Electric and Power Company | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	12		8
Virginia Electric and Power Company | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		25
Virginia Electric and Power Company | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1	[4]
Virginia Electric and Power Company | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	50		1
Total Fair Value, Liabilities	1		31
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	50	[3]	1	[3]
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	2		1
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Assets | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	48		'
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	1		30
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	1		5
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		25
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1	[4]
Virginia Electric and Power Company | Fair Value - Derivatives under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		1
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	3		5
Total Fair Value, Liabilities	11		3
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Assets	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	3	[3]	5	[3]
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Assets | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Assets	3		5
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	11		3
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	11		3
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Current Liabilities | Interest rate	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		0
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		0	[4]
Virginia Electric and Power Company | Fair Value - Derivatives not under Hedge Accounting | Noncurrent Liabilities | Commodity	'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'
Total Fair Value, Liabilities	'		$0
[1]	Noncurrent derivative assets are presented in other deferred charges and other assets in Dominion's Consolidated Balance Sheets.
[2]	Noncurrent derivative liabilities are presented in other deferred credits and other liabilities in Dominion's Consolidated Balance Sheets.
[3]	Current derivative assets are presented in other current assets 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.

Derivatives_and_Hedge_Accounti7

Derivatives and Hedge Accounting Activities (Gains and Losses on our Derivatives in Cash Flow Hedging Relationships) (Details) (Cash Flow Hedges, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	($404)	[1]	($13)	[1]	($115)	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	-130		94		66
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	86	[2]	-25	[2]	-163	[2]
Commodity	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	-481	[1]	71	[1]	137	[1]
Amount of Gain (Loss) Reclassified from AOCI to Income	-115		96		74
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	5	[2]	10	[2]	-20	[2]
Commodity | Operating Revenue	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	-58		188		153
Commodity | Purchased gas	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	-47		-75		-78
Commodity | Electric fuel and other energy-related purchases	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	-10		-17		-2
Commodity | Purchased electric capacity	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	'		'		1
Interest rate	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	77	[1],[3]	-84	[1],[3]	-252	[1],[3]
Amount of Gain (Loss) Reclassified from AOCI to Income	-15	[3]	-2	[3]	-8	[3]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	81	[2],[3]	-35	[2],[3]	-143	[2],[3]
Virginia Electric and Power Company	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	9	[4]	-8	[4]	-9	[4]
Amount of Gain (Loss) Reclassified from AOCI to Income	0		-4		1
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	86	[5]	-25	[5]	-163	[5]
Virginia Electric and Power Company | Commodity	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion)	0	[4]	-2	[4]	-3	[4]
Amount of Gain (Loss) Reclassified from AOCI to Income	0		-4		0
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	5	[5]	10	[5]	-20	[5]
Virginia Electric and Power Company | Commodity | Electric Fuel and Energy Purchases	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Reclassified from AOCI to Income	0		-4		-1
Virginia Electric and Power Company | Commodity | Purchased electric capacity	'		'		'
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)	9	[4],[6]	-6	[4],[6]	-6	[4],[6]
Amount of Gain (Loss) Reclassified from AOCI to Income	0	[6]	0	[6]	1	[6]
Increase (Decrease) in Derivatives Subject to Regulatory Treatment	$81	[5],[6]	($35)	[5],[6]	($143)	[5],[6]
[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 deferred into AOCI have no associated effect in Virginia Power's Consolidated Statements of Income.
[5]	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.
[6]	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in interest and related charges.

Derivatives_and_Hedge_Accounti8

Derivatives and Hedge Accounting Activities (Gains and Losses on our Derivatives Not Designated as Hedging Instruments) (Details) (Derivatives not designated as hedging instruments, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	($83)	[1]	$131	[1]	$26	[1]
Commodity | Operating Revenue	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-45	[1]	168	[1]	111	[1]
Commodity | Purchased gas	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-9	[1]	-14	[1]	-35	[1]
Commodity | Electric fuel and other energy-related purchases	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-29	[1]	-40	[1]	-45	[1]
Interest rate	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	0	[1],[2]	17	[1],[2]	-5	[1],[2]
Virginia Electric and Power Company	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-16	[3]	-50	[3]	-50	[3]
Virginia Electric and Power Company | Commodity	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	-16	[3],[4]	-50	[3],[4]	-45	[3],[4]
Virginia Electric and Power Company | Interest rate	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of Gain (Loss) Recognized in Income on Derivatives	$0	[3],[5]	$0	[3],[5]	($5)	[3],[5]
[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]	Amounts recorded in Dominion's Consolidated Statements of Income are classified in interest and related charges.
[3]	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.
[4]	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in electric fuel and other energy-related purchases.
[5]	Amounts recorded in Virginia Power's Consolidated Statements of Income are classified in interest and related charges.

Earnings_Per_Share_Calculation

Earnings Per Share (Calculation of our Basic and Diluted EPS) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Earnings Per Share [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Net income attributable to Dominion

$431

[1]

$569

$202

$495

($659)

$209

$258

$494

$1,697

$302

[2]

$1,408

[2]

Average shares of common stock outstanding-Basic

'

'

'

'

'

'

'

'

578,700,000

572,900,000

573,100,000

Net effect of potentially dilutive securities

'

'

'

'

'

'

'

'

800,000

[3]

1,000,000

[3]

1,500,000

[3]

Average shares of common stock outstanding-Diluted

'

'

'

'

'

'

'

'

579,500,000

573,900,000

574,600,000

Earnings Per Common Share-Basic (in dollars per share)

$0.74

[1]

$0.98

$0.35

$0.86

($1.15)

$0.36

$0.45

$0.86

$2.93

$0.53

[2]

$2.46

[2]

Earnings Per Common Share-Diluted (in dollars per share)

$0.74

[1]

$0.98

$0.35

$0.86

($1.15)

$0.36

$0.45

$0.86

$2.93

$0.53

[2]

$2.45

[2]

Potentially dilutive securities excluded from the calculation of diluted EPS

'

'

'

'

'

'

'

'

'

0

0

[1]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.

[2]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

[3]

Dilutive securities consist primarily of contingently convertible senior notes. See Note 17 for more information.

Investments_Narrative_Details

Investments (Narrative) (Details) (USD $)

12 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jan. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

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Other operations and maintenance expense

Virginia Electric and Power Company

Virginia Electric and Power Company

Categories of Investments, Marketable Securities, Trading Securities

Categories of Investments, Marketable Securities, Trading Securities

Cost method investments

Cost method investments

Subsequent Event

Pipelines

Pipelines

Pipelines

Blue Racer

Gain (Loss) on Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Investments held in our rabbi trusts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$107

$95

$10

$14

Equity earnings on investments

14

25

35

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Company received distribution from Fowler Ridge in connection with non-recourse permanent financing

33

58

55

115

'

160

115

0

'

'

'

'

'

'

'

'

'

'

'

Carrying amount of Company's investments exceeded its shares of underlying equity

36

30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized interest during construction

28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity method goodwill

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage

'

'

'

50.00%

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

Gain on purchase of business

'

'

'

'

'

'

'

'

'

'

'

'

72

'

'

'

'

'

'

Gain on purchase of business, net of tax

'

'

'

'

'

'

'

'

'

'

'

'

43

'

'

'

'

'

'

Transaction costs on sale

'

'

'

'

'

'

'

'

'

'

'

'

9

'

'

'

'

'

'

Cash proceeds received from sale

'

'

'

'

'

'

'

'

'

47

30

83

'

'

'

'

'

'

'

Gain from sale

'

'

'

'

'

'

'

'

'

25

4

75

'

'

'

'

'

'

'

After tax gain on sale

'

'

'

'

'

'

'

'

'

14

2

42

'

'

'

'

'

'

'

Increase in equity method investment

'

'

'

'

473

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase in equity method investment

'

'

'

'

'

'

'

'

155

'

'

'

'

'

'

'

'

'

'

Restricted cash and cash equivalent for funding qualifying projects

$11

$37

'

'

'

'

'

'

'

'

'

'

'

$8

$10

'

'

'

'

Investments_Marketable_Equity_

Investments (Marketable Equity and Debt Securities and Cash Equivalents (Classified as Available-for-sale) and Cost Method Investments in Decommissioning Trust Funds) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Investment Holdings [Line Items]	'		'
Total amortized cost basis	$2,669		$2,511
Total Unrealized Gains	1,252	[1]	821	[1]
Total Unrealized Losses	-18	[1],[2]	-2	[1],[2]
Fair Value	3,903		3,330
Net assets related to pending sales and purchases of securities	11		6
Fair value of securities in an unrealized loss position	604		195
Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Total amortized cost basis	1,236		1,179
Total Unrealized Gains	538	[1]	337	[1]
Total Unrealized Losses	-9	[1],[3]	-1	[1],[3]
Fair Value	1,765		1,515
Net assets related to pending sales and purchases of securities	6		6
Fair value of securities in an unrealized loss position	299		104
Cost method investments	'		'
Investment Holdings [Line Items]	'		'
Other investments and securities, at cost	106		117
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	106		117
Cost method investments | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Other investments and securities, at cost	106		117
Total Unrealized Gains	0	[1]	0	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	106		117
Cash equivalents and other	'		'
Investment Holdings [Line Items]	'		'
Other investments and securities, at cost	110	[4]	72	[4]
Total Unrealized Gains	0	[1],[4]	0	[1],[4]
Total Unrealized Losses	0	[1],[4]	0	[1],[4]
Fair Value	110	[4]	72	[4]
Cash equivalents and other | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Other investments and securities, at cost	37	[5]	44	[5]
Total Unrealized Gains	0	[1],[5]	0	[1],[5]
Total Unrealized Losses	0	[1],[5]	0	[1],[5]
Fair Value	37	[5]	44	[5]
Corporate debt instruments	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	332		295
Total Unrealized Gains	16	[1]	30	[1]
Total Unrealized Losses	-3	[1]	0	[1]
Fair Value	345		325
Corporate debt instruments | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	185		179
Total Unrealized Gains	8	[1]	17	[1]
Total Unrealized Losses	-2	[1]	0	[1]
Fair Value	191		196
U.S. Treasury securities and agency debentures	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	589		523
Total Unrealized Gains	8	[1]	19	[1]
Total Unrealized Losses	-10	[1]	-2	[1]
Fair Value	587		540
U.S. Treasury securities and agency debentures | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	214		231
Total Unrealized Gains	1	[1]	4	[1]
Total Unrealized Losses	-3	[1]	-1	[1]
Fair Value	212		234
State and municipal	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	297		248
Total Unrealized Gains	11	[1]	26	[1]
Total Unrealized Losses	-5	[1]	0	[1]
Fair Value	303		274
State and municipal | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	163		106
Total Unrealized Gains	4	[1]	11	[1]
Total Unrealized Losses	-4	[1]	0	[1]
Fair Value	163		117
Other	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	3		6
Total Unrealized Gains	0	[1]	1	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	3		7
Other | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	'		1
Total Unrealized Gains	'		0	[1]
Total Unrealized Losses	'		0	[1]
Fair Value	'		1
U.S.: | Equity securities: | Large Cap	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	1,183		1,210
Total Unrealized Gains	1,194	[1]	732	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	2,377		1,942
U.S.: | Equity securities: | Large Cap | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	506		481
Total Unrealized Gains	514	[1]	298	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	1,020		779
U.S.: | Equity securities: | Other	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	49		40
Total Unrealized Gains	23	[1]	13	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	72		53
U.S.: | Equity securities: | Other | Virginia Electric and Power Company	'		'
Investment Holdings [Line Items]	'		'
Amortized Cost	25		20
Total Unrealized Gains	11	[1]	7	[1]
Total Unrealized Losses	0	[1]	0	[1]
Fair Value	$36		$27
[1]	Included in AOCI and the decommissioning trust regulatory liability as discussed in Note 2.
[2]	The fair value of securities in an unrealized loss position was $604 million and $195 million at December 31, 2013 and 2012, respectively.
[3]	The fair value of securities in an unrealized loss position was $299 million and $104 million at December 31, 2013 and 2012, respectively.
[4]	Includes pending sales of securities of $11 million and pending purchases of securities of $6 million at December 31, 2013 and 2012, respectively.
[5]	Includes pending sales of securities of $6 million at December 31, 2013 and 2012.

Investments_Fair_Value_of_our_

Investments (Fair Value of our Marketable Debt Securities by Contractual Maturity) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Schedule of Available-for-sale Securities [Line Items]	'
Due in one year or less	$128
Due after one year through five years	357
Due after five years through ten years	362
Due after ten years	391
Total	1,238
Virginia Electric and Power Company	'
Schedule of Available-for-sale Securities [Line Items]	'
Due in one year or less	31
Due after one year through five years	163
Due after five years through ten years	196
Due after ten years	176
Total	$566

Investments_Selected_Informati

Investments (Selected Information Regarding Marketable Equity and Debt Securities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Available-for-sale securities:	'		'		'
Proceeds from sales	$1,476		$1,356		$1,757
Realized gains	157	[1]	98	[1]	79	[1]
Realized losses	33	[1]	33	[1]	92	[1]
Virginia Electric and Power Company	'		'		'
Available-for-sale securities:	'		'		'
Proceeds from sales	572		626		1,030
Realized gains	52	[1]	42	[1]	34	[1]
Realized losses	$14	[1]	$11	[1]	$34	[1]
[1]	Includes realized gains and losses recorded to the decommissioning trust regulatory liability as discussed in Note 2.

Investments_Recorded_OtherThan

Investments (Recorded Other-Than-Temporary Impairment Losses on Investments) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Total other-than-temporary impairment losses	$31		$26		$75
Losses recorded to decommissioning trust regulatory liability	-13		-10		-24
Losses recognized in other comprehensive income (before taxes)	10		2		3
Net impairment losses recognized in earnings	8		14		48
Other-than-temporary impairment losses for debt securities	18		4		6
Virginia Electric and Power Company	'		'		'
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Total other-than-temporary impairment losses	15	[1]	11	[1]	29	[1]
Losses recorded to decommissioning trust regulatory liability	-13		-10		-24
Losses recognized in other comprehensive income (before taxes)	1		0		1
Net impairment losses recognized in earnings	1		1		4
Other-than-temporary impairment losses for debt securities	$9		$2		$4
[1]	Amounts include other-than-temporary impairment losses for debt securities of $9 million, $2 million and $4 million at December 31, 2013, 2012 and 2011, respectively.

Investments_Investments_Under_

Investments (Investments Under Equity Method of Accounting) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]	'		'
Investment Balance	$916		$558
Commitment to invest in clean power and technology	50		'
Blue Racer Midstream LLC	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Ownership%	50.00%		'
Investment Balance	510		39
Description	'Midstream gas and related services		'
Fowler I Holdings LLC	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Ownership%	50.00%		'
Investment Balance	149		158
Description	'Wind-powered merchant generation facility		'
NedPower Mount Storm LLC	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Ownership%	50.00%		'
Investment Balance	131		137
Description	'Wind-powered merchant generation facility		'
Iroquois Gas Transmission System, LP	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Ownership%	24.72%		'
Investment Balance	105		102
Description	'Gas transmission system		'
Elwood Energy LLC	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Ownership%	0.00%	[1]	50.00%	[1]
Investment Balance	0	[1]	117	[1]
Description	'Natural gas-fired merchant generation peaking facility	[1]	'
Ownership retained in cost method investment	0.50%	[1]	'
Other	'		'
Schedule of Equity Method Investments [Line Items]	'		'
Investment Balance	$21	[2]	$5	[2]
[1]	Following the 2013 sale of Elwood, at December 31, 2013, Dominion retained a 0.5% cost method investment. At December 31, 2012, Dominion owned 50% and Elwood was therefore considered an equity method investment.
[2]	Dominion has a $50 million commitment to invest in clean power and technology businesses through 2018.

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Narrative) (Details) (Oil and Gas Properties, USD $)	1 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2013
	Natural_Gas_Producer	acre
	acre
Oil and Gas Properties	'	'
Property, Plant and Equipment [Line Items]	'	'
Number of natural gas producers	2	'
Acres of Marcellus Shale rights	100,000	100,000
Agreed upon payments for conveyance of acres of natural gas storage fields	$200	$200
Period for payments related to conveyance of natural gas storage fields	'9 years	'
Cash proceeds received from sale	'	100
Gain from sale	'	20
After tax gain on sale	'	12
Deferred Revenue, Additions	'	$80

Property_Plant_and_Equipment_P

Property, Plant and Equipment (Property, Plant and Equipment) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Utility:	'		'
Generation	$14,018		$13,707
Transmission	8,686		7,799
Distribution	11,714		11,071
Storage	2,190		2,137
Nuclear fuel	1,375		1,277
Gas gathering and processing	787		803
General and other	812		803
Other-including plant under construction	3,261		2,232
Total utility	42,843		39,829
Nonutility:	'		'
Merchant generation-nuclear	1,153		1,163
Merchant generation-other	1,328	[1]	1,289	[1]
Nuclear fuel	770		775
Other-including plant under construction	875		1,265
Total nonutility	4,126		4,492
Total property, plant and equipment	46,969		44,321
Merchant generation other, due to consolidation of VIE	'		957
Virginia Electric and Power Company	'		'
Utility:	'		'
Generation	14,018		13,707
Transmission	4,959		4,261
Distribution	9,103		8,701
Nuclear fuel	1,375		1,277
General and other	668		659
Other-including plant under construction	2,719		2,017
Total utility	32,842		30,622
Nonutility:	'		'
Total nonutility	6		9
Total property, plant and equipment	$32,848		$30,631
[1]	2012 amount includes $957 million due to consolidation of a VIE. See Note 15 for further information.

Property_Plant_and_Equipment_S

Property, Plant and Equipment (Share of Jointly-Owned Power Stations) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Millstone Unit 3	'
Jointly Owned Utility Plant Interests [Line Items]	'
Ownership interest	93.50%	[1]
Plant in service	$1,007	[1]
Accumulated depreciation	-262	[1]
Nuclear fuel	388	[1]
Accumulated amortization of nuclear fuel	-283	[1]
Plant under construction	69	[1]
Virginia Electric and Power Company | Bath County Pumped Storage Station	'
Jointly Owned Utility Plant Interests [Line Items]	'
Ownership interest	60.00%	[2]
Plant in service	1,038	[2]
Accumulated depreciation	-536	[2]
Nuclear fuel	0	[2]
Accumulated amortization of nuclear fuel	0	[2]
Plant under construction	23	[2]
Virginia Electric and Power Company | North Anna	'
Jointly Owned Utility Plant Interests [Line Items]	'
Ownership interest	88.40%	[2]
Plant in service	2,486	[2]
Accumulated depreciation	-1,109	[2]
Nuclear fuel	597	[2]
Accumulated amortization of nuclear fuel	-434	[2]
Plant under construction	76	[2]
Virginia Electric and Power Company | Clover Power Station	'
Jointly Owned Utility Plant Interests [Line Items]	'
Ownership interest	50.00%	[2]
Plant in service	568	[2]
Accumulated depreciation	-199	[2]
Nuclear fuel	0	[2]
Accumulated amortization of nuclear fuel	0	[2]
Plant under construction	$6	[2]
[1]	Unit jointly owned by Dominion.
[2]	Units jointly owned by Virginia Power.

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Goodwill [Line Items]	'	'	'
Amortization expense for intangible assets	$72	$82	$78
Acquisition of intangible assets	81	'	'
Weighted-average amortization period (years)	'10 years	'	'
Virginia Electric and Power Company	'	'	'
Goodwill [Line Items]	'	'	'
Amortization expense for intangible assets	22	'	'
Acquisition of intangible assets	$14	'	'
Weighted-average amortization period (years)	'5 years	'	'

Goodwill_and_Intangible_Assets2

Goodwill and Intangible Assets (Goodwill) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Goodwill [Roll Forward]	'		'
Goodwill, Beginning Balance	$3,130	[1]	$3,141	[1]
Asset disposition adjustment	-44		-11
Goodwill, Ending Balance	3,086	[1]	3,130	[1]
Dominion Generation	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Beginning Balance	1,503	[1],[2]	1,503	[1],[2]
Asset disposition adjustment	-19	[3]	0
Goodwill, Ending Balance	1,484	[1]	1,503	[1],[2]
Dominion Energy	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Beginning Balance	701	[1]	712	[1]
Asset disposition adjustment	-25	[4]	-11	[4]
Goodwill, Ending Balance	676	[1]	701	[1]
DVP	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Beginning Balance	926	[1]	926	[1],[2]
Asset disposition adjustment	0		0
Goodwill, Ending Balance	926	[1]	926	[1]
Corporate and Other	'		'
Goodwill [Roll Forward]	'		'
Goodwill, Beginning Balance	0	[1],[5]	0	[1],[5]
Asset disposition adjustment	0	[5]	0	[5]
Goodwill, Ending Balance	$0	[1],[5]	$0	[1],[5]
[1]	Goodwill amounts do not contain any accumulated impairment losses.
[2]	Recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.
[3]	See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.
[4]	Related to assets sold or contributed to Blue Racer.
[5]	Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.

Goodwill_and_Intangible_Assets3

Goodwill and Intangible Assets (Components of Intangible Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	$870	$864
Accumulated Amortization	310	328
Virginia Electric and Power Company	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	271	303
Accumulated Amortization	78	122
Software, licenses and other	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	867	859
Accumulated Amortization	308	327
Software, licenses and other | Virginia Electric and Power Company	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	271	303
Accumulated Amortization	78	122
Emissions allowances	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	3	5
Accumulated Amortization	$2	$1

Goodwill_and_Intangible_Assets4

Goodwill and Intangible Assets (Annual Amortization Expense of Intangible Assets) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'
2014	$69
2015	59
2016	50
2017	40
2018	29
Virginia Electric and Power Company	'
Finite-Lived Intangible Assets [Line Items]	'
2014	21
2015	15
2016	12
2017	9
2018	$5

Regulatory_Assets_and_Liabilit2

Regulatory Assets and Liabilities (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets represented past expenditures not earning return	$129	'
Period expenditures expected to be recovered (years)	'2 years	'
DOE Claims	2,129	1,650
Virginia Electric and Power Company	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
Regulatory assets represented past expenditures not earning return	63	'
DOE Claims	1,638	1,317
DOE Claims	'	'
Regulatory Assets And Liabilities [Line Items]	'	'
DOE Claims	$5	'

Regulatory_Assets_and_Liabilit3

Regulatory Assets and Liabilities (Regulatory Assets and Liabilities) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Regulatory Assets And Liabilities [Line Items]	'		'
Deferred rate adjustment clause costs	$89	[1]	$55	[1]
Unrecovered gas costs	50	[2]	59	[2]
Virginia sales taxes	46	[3]	37	[3]
Derivatives	16	[4]	0	[4]
Plant retirement	1	[5]	25	[5]
Other	15		27
Regulatory assets-current	217	[6]	203	[6]
Unrecognized pension and other postretirement benefit costs	706	[7]	1,210	[7]
Deferred rate adjustment clause costs	287	[1]	173	[1]
Income taxes recoverable through future rates	155	[8]	140	[8]
Derivatives	16	[4]	105	[4]
Other postretirement benefit costs	12	[9]	21	[9]
Plant retirement	10	[5]	11	[5]
Other	42		57
Regulatory assets-non-current	1,228		1,717
Total regulatory assets	1,445		1,920
PIPP, regulatory liabilities-current	76	[10]	100	[10]
Deferred cost of fuel used in electric generation	24	[11]	7	[11]
Other	28		29
Regulatory liabilities-current	128	[12]	136	[12]
Provision for future cost of removal and AROs	1,028		985
Decommissioning trust	693		501
Unrecognized pension and other postretirement benefit costs	174	[7]	2	[7]
Deferred cost of fuel used in electric generation	90	[11]	13	[11]
Other	16		13
Regulatory liabilities-non-current	2,001		1,514
Total regulatory liabilities	2,129		1,650
Virginia Electric and Power Company	'		'
Regulatory Assets And Liabilities [Line Items]	'		'
Deferred rate adjustment clause costs	62	[1]	51	[1]
Virginia sales taxes	46	[3]	37	[3]
Derivatives	16	[4]	0	[4]
Plant retirement	1	[5]	25	[5]
Other	3		6
Regulatory assets-current	128		119
Deferred rate adjustment clause costs	227	[1]	127	[1]
Income taxes recoverable through future rates	124	[8]	110	[8]
Derivatives	16	[4]	105	[4]
Plant retirement	10	[5]	11	[5]
Other	40		43
Regulatory assets-non-current	417		396
Total regulatory assets	545		515
Deferred cost of fuel used in electric generation	24	[11]	7	[11]
Other	17		25
Regulatory liabilities-current	41		32
Provision for future cost of removal	807	[13]	763	[13]
Decommissioning trust	693	[14]	501	[14]
Deferred cost of fuel used in electric generation	90	[11]	14	[11]
Other	7		7
Regulatory liabilities-non-current	1,597		1,285
Total regulatory liabilities	$1,638		$1,317
[1]	Reflects deferrals under the electric transmission FERC formula rate and the deferral of costs associated with certain current and prospective rider projects. See Note 13 for more information.
[2]	Reflects unrecovered gas costs at Dominion's regulated gas operations, which are recovered through annual filings with the applicable regulatory authority.
[3]	Amounts to be recovered through an annual surcharge to reimburse Virginia Power for incremental sales taxes being incurred due to the repeal of the public service company sales tax exemption in Virginia
[4]	As discussed under Derivative Instruments in Note 2, 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.
[5]	Reflects costs anticipated to be recovered in North Carolina base rates for certain coal units expected to be retired.
[6]	Current regulatory assets are presented in other current assets in Dominion's Consolidated Balance Sheets.
[7]	Represents unrecognized pension and other postretirement benefit costs expected to be recovered through future rates generally over the expected remaining service period of plan participants by certain of Dominion's rate-regulated subsidiaries.
[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]	Primarily reflects costs recognized in excess of amounts included in regulated rates charged by Dominion's regulated gas operations before rates were updated to reflect a change in accounting method for other postretirement benefit costs.
[10]	Under PIPP, eligible customers can receive energy assistance based on their ability to pay. The difference between the customer's total bill and the PIPP plan amount is deferred and collected or returned annually under the PIPP rider according to East Ohio tariff provisions. See Note 13 for more information regarding PIPP.
[11]	Primarily reflects deferred fuel expenses for the Virginia jurisdiction of Virginia Power's generation operations. For 2013, amount includes approximately $5 million related to DOE claims. See Note 13 for more information.
[12]	Current regulatory liabilities are presented in other current liabilities in Dominion's Consolidated Balance Sheets.
[13]	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.
[14]	Primarily reflects a regulatory liability representing amounts collected from Virginia jurisdictional customers and placed in external trusts (including income, losses and changes in fair value thereon) for the future decommissioning of Virginia Power's utility nuclear generation stations, in excess of the related ARO.

Regulatory_Matters_Narrative_D

Regulatory Matters (Narrative) (Details) (USD $)

12 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

31-May-12

Mar. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 01, 2008

Jul. 31, 2008

Nov. 30, 2013

31-May-13

Dec. 31, 2013

Oct. 31, 2013

Nov. 30, 2013

Nov. 30, 2013

Sep. 30, 2013

Jul. 31, 2013

Dec. 31, 2013

Nov. 30, 2013

Jun. 30, 2013

Nov. 30, 2013

Jun. 30, 2013

31-May-13

Aug. 31, 2013

Aug. 31, 2013

31-May-13

Jul. 31, 2008

Jul. 31, 2008

Dec. 31, 2013

Dec. 31, 2013

Nov. 30, 2013

Feb. 28, 2013

Dec. 31, 2008

Mar. 31, 2013

Mar. 31, 2013

Dec. 31, 2013

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

East Ohio

East Ohio

East Ohio

East Ohio

East Ohio

DTI

Project

Project

Virginia Regulation

Virginia Regulation

Virginia Regulation

Loudoun- Pleasant View Transmission

Surry Switching Station Transmission Line

Transmission Line from Skiffes Creek Switching Station to Wheaton Substation

Bremo Power Station

North Anna

North Anna

Minimum

Rider B

Rider BW

Rider S

Rider W

Rider C1A

Rider C2A

Rider T1

1.5% Incentive rate for projects

1.25% Incentive rate for projects

Other Current Liabilities

Noncurrent Regulatory Liability

PIR Program

PIR Program

PIR Program

PIPP Plus Program

PIPP Plus Program

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Surry Switching Station Transmission Line

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Virginia Regulation

Project

Project

Virginia Regulation

Virginia Regulation

Ohio Regulation

Ohio Regulation

Ohio Regulation

Ohio Regulation

Ohio Regulation

kV

kV

kV

MW

Part

Virginia Regulation

mi

Scenario, Forecast

mi

mi

Regulatory Matters [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Approved ROE

'

'

'

'

'

'

11.40%

'

'

'

'

10.90%

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of electric transmission projects

'

'

'

'

'

'

'

'

'

11

11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

7

'

'

'

'

'

'

'

'

Incentive for 4 electric transmission enhancement projects

'

'

'

'

'

'

1.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive for 7 electric transmission enhancement projects

'

'

'

'

'

'

1.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of electric transmission projects cancelled

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated cost of project abandonment

'

'

'

'

'

'

$7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of transmission projects approved

'

'

'

'

'

'

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated cost for electric transmission projects

'

'

'

'

'

'

857,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Costs claimed to be unjust and excluded from transmission formula rate

'

'

'

'

223,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Potential settlement required annual payment for 10 years

'

'

'

250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Settlement payment duration

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Earned ROE percentage

'

'

'

'

'

'

'

'

'

'

'

10.25%

'

10.30%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis points below authorized ROE

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of deferred recovery costs authorized

'

'

'

'

'

'

'

'

'

'

'

23,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of revenue sufficiency

'

'

'

'

'

'

'

'

'

'

'

280,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Charge related to Biennial Review Order

'

'

'

'

'

'

'

'

'

'

'

'

'

55,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restoration costs net of tax

'

'

'

'

'

28,000,000

'

'

'

'

'

'

'

37,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Peer group floor ROE, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

9.89%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Market cost of equity, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proposed increase decrease revenue requirement

'

'

'

'

'

'

'

'

'

'

'

'

162,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Approved fuel factor rate

'

'

'

'

'

'

'

'

'

'

'

0.02942

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Requested fuel factor rate

'

'

'

'

'

'

'

'

'

'

'

0.02572

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of expected reduction in anticipated fuel recoveries

'

'

'

'

'

'

'

'

'

'

'

140,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities related to fuel recoveries

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24,000,000

85,000,000

'

'

'

'

'

'

Proposed revenue requirement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

16,000,000

'

248,000,000

101,000,000

'

'

404,000,000

'

'

'

'

'

'

'

'

'

'

Proposed revenue requirement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101,000,000

'

'

1,000,000

35,000,000

'

'

'

'

'

'

'

'

'

'

'

Capacity of Electricity (in Megawatts)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

227

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expected cost of proposed conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

53,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of parts of amendment to COL application

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period after completion of seismic assessment to submit motion to reopen proceeding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'60 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of development costs incurred that are recoverable through future rate adjustment clause

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Plant construction and other property additions (including nuclear fuel)

4,104,000,000

4,145,000,000

3,652,000,000

'

'

'

2,394,000,000

2,082,000,000

1,885,000,000

'

'

'

'

'

'

'

'

'

'

570,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Projected amount of capitalized costs recovered, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

70.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

KV Line

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500

500

230

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Length of Transmission line

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20

'

'

'

7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage replacement of pipeline system

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20.00%

'

'

'

Miles of pipeline identified to be replaced

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,100

'

'

'

Period for pipeline replacement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

'

'

Total plant investment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

170,000,000

148,000,000

'

'

'

'

Cumulative gross plant investment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

681,000,000

511,000,000

'

'

'

'

Approved revenue requirement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90,000,000

67,000,000

'

'

'

'

Refund of overrecovery of accumulated arrearages

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

91,000,000

'

'

Recovery of projected deferred program costs

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

54,000,000

'

Amount that agreement could reduce revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$35,000,000

Asset_Retirement_Obligations_N

Asset Retirement Obligations (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Asset Retirement Obligations [Line Items]	'	'
Fair value, primarily of equity and debt securities	$3,900,000,000	$3,300,000,000
Nuclear decommissioning trust funds	3,903,000,000	3,330,000,000
Virginia Electric and Power Company	'	'
Asset Retirement Obligations [Line Items]	'	'
Nuclear decommissioning trust funds	$1,765,000,000	$1,515,000,000

Asset_Retirement_Obligations_C

Asset Retirement Obligations (Changes to AROs) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'		'
AROs, Beginning balance	$1,705	[1]	$1,398	[1]	'
Obligations incurred during the period	13		24		'
Obligations settled during the period	-68		-13		'
Revisions in estimated cash flows	-129	[2]	242	[3]	'
Accretion	-86		-77		'
Other	-29		-23		'
AROs , Ending balance	1,578	[1]	1,705	[1]	'
Other current liabilities	94		64		15
Virginia Electric and Power Company	'		'		'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'		'		'
AROs, Beginning balance	705		625	[4]	'
Obligations incurred during the period	2		18		'
Obligations settled during the period	-2		-1		'
Revisions in estimated cash flows	-52	[2]	41	[5]	'
Accretion	-38		-34		'
Other	-2		-12		'
AROs , Ending balance	689		705		'
Asset retirement obligation	'		$1		'
[1]	Includes $15 million, $64 million and $94 million reported in other current liabilities at December 31, 2011, 2012, and 2013, respectively.
[2]	Primarily reflects lower anticipated nuclear decommissioning costs.
[3]	Primarily reflects the accelerated timing of the decommissioning of Kewaunee that began in 2013.
[4]	Includes $1 million reported in other current liabilities.
[5]	Primarily reflects the effect of higher anticipated nuclear decommissioning costs.

Variable_Interest_Entities_Nar

Variable Interest Entities (Narrative) (Details) (USD $)	12 Months Ended			1 Months Ended	110 Months Ended		12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Aug. 31, 2013	Aug. 31, 2013	Oct. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
				Juniper	Juniper	Juniper	Virginia Electric and Power Company	Virginia Electric and Power Company	Virginia Electric and Power Company
							MW
Variable Interest Entity [Line Items]	'	'	'	'	'	'	'	'	'
Aggregate generation capacity from long-term power and capacity contracts (MW)	'	'	'	'	'	'	870	'	'
Contracts exprity date start range	'	'	'	'	'	'	'2015	'	'
Contracts exprity date end range	'	'	'	'	'	'	'2021	'	'
Remaining purchase commitments	'	'	'	'	'	'	$900,000,000	'	'
Payment for electric capacity	'	'	'	'	'	'	217,000,000	214,000,000	211,000,000
Payment for electric energy	'	'	'	'	'	'	98,000,000	83,000,000	125,000,000
Shared services purchased	'	'	'	'	'	'	331,000,000	328,000,000	389,000,000
Annual lease payments	'	'	'	'	53,000,000	'	'	'	'
Fair value of property plant and equipment	'	'	'	'	'	957,000,000	'	'	'
Amount of debt expected to be recorded from consolidation	'	'	'	'	'	896,000,000	'	'	'
Amount of non-controlling interest expected to be recorded from consolidation	'	'	'	'	'	61,000,000	'	'	'
Acquisition of Juniper noncontrolling interest in Fairless	$923,000,000	$0	$0	$923,000,000	'	'	'	'	'

ShortTerm_Debt_And_Credit_Agre2

Short-Term Debt And Credit Agreements (Commercial Paper, Bank Loans, and Letters of Credit Outstanding, as well as Capacity Available Under Credit Facilities (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
Short term Debt [Line Items]	'		'
Facility Limit	$3,500,000,000		$3,500,000,000
Outstanding Commercial Paper	1,927,000,000	[1]	2,412,000,000	[1]
Outstanding Letters of Credit	11,000,000		26,000,000
Facility Capacity Available	1,562,000,000		1,062,000,000
Weighted-average interest rates of the outstanding commercial paper	0.33%		0.49%
Virginia Electric and Power Company	'		'
Short term Debt [Line Items]	'		'
Facility Limit	1,250,000,000		1,250,000,000
Outstanding Commercial Paper	842,000,000	[2]	992,000,000	[2]
Outstanding Letters of Credit	1,000,000		2,000,000
Facility Capacity Available	407,000,000		256,000,000
Weighted-average interest rates of the outstanding commercial paper	0.33%		0.47%
Credit facility	120,000,000		'
Credit Facility 1.5 Billion	'		'
Short term Debt [Line Items]	'		'
Facility Limit	3,000,000,000	[3]	3,000,000,000	[3]
Outstanding Commercial Paper	1,927,000,000	[3]	2,412,000,000	[3]
Outstanding Letters of Credit	0	[3]	0	[3]
Facility Capacity Available	1,073,000,000	[3]	588,000,000	[3]
Credit facility, to support letters of credit	1,500,000,000		'
Credit Facility 1.5 Billion | Virginia Electric and Power Company	'		'
Short term Debt [Line Items]	'		'
Facility Limit	1,000,000,000	[4]	1,000,000,000	[4]
Outstanding Commercial Paper	842,000,000	[4]	992,000,000	[4]
Outstanding Letters of Credit	0	[4]	0	[4]
Facility Capacity Available	158,000,000	[4]	8,000,000	[4]
Credit facility, to support letters of credit	1,500,000,000		'
Credit Facility 500 million	'		'
Short term Debt [Line Items]	'		'
Facility Limit	500,000,000	[5]	500,000,000	[5]
Outstanding Commercial Paper	0	[5]	0	[5]
Outstanding Letters of Credit	11,000,000	[5]	26,000,000	[5]
Facility Capacity Available	489,000,000	[5]	474,000,000	[5]
Amount of committed capacity extended	400,000,000		'
Amount of capacity not extended	100,000,000		'
Credit Facility 500 million | Virginia Electric and Power Company	'		'
Short term Debt [Line Items]	'		'
Facility Limit	250,000,000	[6]	250,000,000	[6]
Outstanding Commercial Paper	0	[6]	0	[6]
Outstanding Letters of Credit	1,000,000	[6]	2,000,000	[6]
Facility Capacity Available	249,000,000	[6]	248,000,000	[6]
Tax-Exempt Financings | Virginia Electric and Power Company	'		'
Short term Debt [Line Items]	'		'
Variable rate tax-exempt financings	$119,000,000		'
[1]	The weighted-average interest rates of the outstanding commercial paper supported by Dominion's credit facilities were 0.33% and 0.49% at December 31, 2013 and 2012, respectively.
[2]	The weighted-average interest rates of the outstanding commercial paper supported by these credit facilities were 0.33% and 0.47% at December 31, 2013 and 2012, respectively.
[3]	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.5 billion of letters of credit.
[4]	Effective September 2013, the maturity date was extended from September 2017 to September 2018. This credit facility 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. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.
[5]	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances.
[6]	Effective September 2013, the maturity date for $400 million of the $500 million committed capacity was extended from September 2017 to September 2018. Also effective September 2013, the maturity date for the remaining $100 million was extended from September 2016 to September 2018. This credit facility can be used to support bank borrowings, commercial paper and letter of credit issuances. Virginia Power's current sub-limit under this credit facility can be increased or decreased multiple times per year.

LongTerm_Debt_Narrative_Detail

Long-Term Debt (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

Jan. 31, 2013

Sep. 30, 2011

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2013

Jul. 31, 2016

Apr. 30, 2016

Jul. 31, 2016

Apr. 30, 2016

Jun. 30, 2013

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2013

Dec. 31, 2013

Jul. 01, 2006

Jun. 30, 2006

Feb. 28, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2011

Sep. 30, 2011

Sep. 30, 2006

Jun. 30, 2010

Jun. 30, 2009

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 22, 2013

Jan. 31, 2013

Jan. 31, 2014

Feb. 26, 2014

Feb. 28, 2014

Feb. 28, 2014

Iroquois Gas Transmission System, L.P.

Scenario, Forecast

Scenario, Forecast

Scenario, Forecast

Scenario, Forecast

Scenario, Forecast

Capital Unit, Class A

Capital Unit, Class A

Capital Unit, Class B

Capital Unit, Class B

Common Stock

June 2006 hybrids

June 2006 hybrids

September 2006 hybrids

September 2006 hybrids

September 2006 hybrids

September 2006 hybrids

September 2006 hybrids

September 2006 hybrids

June 2009 hybrids

June 2009 hybrids

Convertible Debt

Enhanced Junior Subordinated Notes

Enhanced Junior Subordinated Notes

Enhanced Junior Subordinated Notes

Senior Notes

7.83% Debentures due 12/1/2027

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Minimum

Minimum

Maximum

Maximum

Unsecured Senior Notes

Senior Notes

Senior Notes

Senior Notes Maturing in 2024

Senior Notes Maturing in 2044

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding contingent convertible senior notes

'

'

$43,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion rate adjustment (shares)

'

'

$29.88

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Principal Amount of Senior Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,000

'

'

'

'

'

'

'

'

'

Conversion price (per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$33.47

'

'

'

'

'

'

'

'

'

Shares of stock issued if all converted

'

'

'

'

600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends declared payable (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$60

'

'

'

Conversion rate (shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$30.00

'

'

Average trading price principal amount of the senior notes

'

'

120.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum consecutive trading days

'

'

'20 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum consecutive trading days

'

'

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Convertible senior notes converted by holders

'

'

39,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares issued in excess of principal amounts related to converted securities

'

'

28,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption rate

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Noncontrolling interest, ownership percentage by parent

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beneficial ownership percentage

'

'

97.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beneficial ownership interest

'

'

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage in capital trust assets

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Junior subordinated notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

500,000,000

'

685,000,000

'

'

'

'

'

258,000,000

'

'

'

'

RSN Annual Interest Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.83%

7.50%

'

'

'

'

2.30%

6.30%

8.38%

'

'

'

'

'

'

7.83%

'

'

3.45%

4.45%

Redemption of units of Dominion Resources Capital Trust I capital securities

250,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dominion Resources Capital Trust I capital securities

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate of Dominion Resources Capital Trust I capital securities

7.83%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption price per capital security

$1,019.58

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest charges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

21,000,000

21,000,000

'

'

'

'

'

'

Deferral

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period for consideration of proceeds (days)

'

'180 days

'365 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchased and cancelled of junior subordinated notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000,000

86,000,000

16,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Tender offer to purchase additional hybrids

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity units issued

'

'

'

'

'

'

'

'

'

550,000,000

'

550,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment rate on Equity Units

'

'

'

'

'

'

'

'

'

'

6.13%

'

6.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage interest on RSN issued by Dominion

'

'

5.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase price to be paid under stock purchase contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

$50

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares to be issued under purchase contracts

'

'

'

'

'

8,400,000

8,400,000

9,900,000

9,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares reserved and available for issuance

'

'

22,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

General partnership interest in Iroquois

'

'

'

24.72%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Long-term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,200,000,000

'

'

'

$350,000,000

$400,000,000

LongTerm_Debt_Total_Long_Term_

Long-Term Debt (Total Long Term Debt) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

31-May-13

Jun. 30, 2013

1.4% to 7.195%, due 2013 to 2018

2.75% to 8.875% due 2018 to 2042

Unsecured Convertible Senior Notes, 2.125%, due 2023

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts, 7.83% and 8.4%, due 2027 and 2031

7.5% and 8.375%, due 2064 and 2066

Remarketable Subordinated Notes, 1.07% and 1.18%, due 2019 and 2021

5.0% and 6.625%, due 2013 and 2014

6.8% and 6.875%, due 2026 and 2027

Secured Senior Notes, 5.13% to 5.78%, due 2013

Secured Senior Note, 7.33%, due 2020

2.25% to 5.75%, due 2033 to 2042

5.25% Senior Notes Due 2033

8.875% Senior Notes Due 2019

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Tax-Exempt Financings

Tax-Exempt Financings

Tax-Exempt Financings

Tax-Exempt Financings

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

Junior Subordinated Notes

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Kincaid Power Station

Brayton Point

Variable rates, due 2013 and 2014

Variable rates, due 2013 and 2014

1.4% to 7.195%, due 2013 to 2018

1.4% to 7.195%, due 2013 to 2018

2.75% to 8.875% due 2018 to 2042

2.75% to 8.875% due 2018 to 2042

Unsecured Convertible Senior Notes, 2.125%, due 2023

Unsecured Convertible Senior Notes, 2.125%, due 2023

Remarketable Subordinated Notes, 1.07% and 1.18%, due 2019 and 2021

Remarketable Subordinated Notes, 1.07% and 1.18%, due 2019 and 2021

5.0% and 6.625%, due 2013 and 2014

5.0% and 6.625%, due 2013 and 2014

6.8% and 6.875%, due 2026 and 2027

6.8% and 6.875%, due 2026 and 2027

Unsecured Senior Notes, 1.05% to 4.8%, due 2016 to 2043

Unsecured Senior Notes, 1.05% to 4.8%, due 2016 to 2043

Secured Senior Notes, 5.13% to 5.78%, due 2013

Secured Senior Notes, 5.13% to 5.78%, due 2013

Secured Senior Note, 7.33%, due 2020

Secured Senior Note, 7.33%, due 2020

Variable rate, due 2041

Variable rate, due 2041

2.25% to 5.75%, due 2033 to 2042

2.25% to 5.75%, due 2033 to 2042

Variable rate, due 2041

Variable rate, due 2041

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts, 7.83% and 8.4%, due 2027 and 2031

Unsecured Junior Subordinated Notes Payable to Affiliated Trusts, 7.83% and 8.4%, due 2027 and 2031

7.5% and 8.375%, due 2064 and 2066

7.5% and 8.375%, due 2064 and 2066

Enhanced Junior Subordinated Notes, variable rate, due 2066

Enhanced Junior Subordinated Notes, variable rate, due 2066

Line of Credit

1.2% to 8.625%, due 2013 to 2018

2.75% to 8.875%, due 2019 to 2043

1.5% to 5.6%, due 2022 to 2040

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Tax-Exempt Financings

Tax-Exempt Financings

Tax-Exempt Financings

Tax-Exempt Financings

Secured Senior Note, 7.33%, due 2020

Tax-Exempt Financings

1.2% to 8.625%, due 2013 to 2018

1.2% to 8.625%, due 2013 to 2018

2.75% to 8.875%, due 2019 to 2043

2.75% to 8.875%, due 2019 to 2043

Variable rates, due 2016 to 2041

Variable rates, due 2016 to 2041

1.5% to 5.6%, due 2022 to 2040

1.5% to 5.6%, due 2022 to 2040

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total principal, including VIE

$20,842,000,000

$18,988,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$400,000,000

$400,000,000

$3,291,000,000

$3,541,000,000

$4,599,000,000

$4,599,000,000

$43,000,000

$82,000,000

$1,100,000,000

$0

$600,000,000

$622,000,000

$89,000,000

$89,000,000

$1,200,000,000

$0

$0

$842,000,000

$0

$145,000,000

$75,000,000

$0

$27,000,000

$284,000,000

$0

$75,000,000

$10,000,000

$268,000,000

$985,000,000

$985,000,000

$380,000,000

$380,000,000

$8,043,000,000

$6,676,000,000

'

'

'

'

$2,138,000,000

$2,306,000,000

$4,993,000,000

$3,408,000,000

$606,000,000

$454,000,000

$306,000,000

$508,000,000

'

'

Securities due within one year, including VIE

-1,519,000,000

-2,223,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-58,000,000

-418,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized discount and premium, net

-48,000,000

-7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-11,000,000

-7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long term debt, including VIE

19,330,000,000

16,851,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,974,000,000

6,251,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value hedge valuation

55,000,000

93,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2013 Weighted- average Coupon

2.95%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.37%

'

4.03%

'

5.64%

'

'

'

1.13%

'

5.00%

'

6.81%

'

3.13%

'

'

'

'

'

1.12%

'

2.38%

'

'

'

8.40%

'

8.11%

'

2.58%

'

4.10%

'

'

'

'

'

5.09%

'

5.25%

'

0.98%

'

3.16%

'

'

'

Debt instrument interest rate minimum

'

'

'

1.40%

2.75%

'

7.83%

7.50%

1.07%

5.00%

6.80%

5.03%

'

2.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.20%

2.75%

1.50%

'

'

'

'

'

'

'

'

'

'

Debt instrument interest rate maximum

'

'

'

7.20%

8.88%

'

8.40%

8.38%

1.18%

6.63%

6.88%

5.78%

'

5.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.63%

8.75%

5.60%

'

'

'

'

'

'

'

'

'

'

Credit facility, to support letters of credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

120,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

510,000,000

600,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

RSN Annual Interest Rate

'

'

'

'

'

2.13%

'

'

'

'

'

'

7.33%

'

5.25%

8.88%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long term debt maturity date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2033

'2019

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Redemption percentage of principal and accrued interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of the applicable conversion price

120.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum consecutive trading days

'20 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum consecutive trading days

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

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'

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'

'

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'

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'

'

'

'

'

'

'

'

'

'

Redemption percentage of principal amount

100.00%

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unamortized premium

'

18,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of notes redeemed

1,245,000,000

1,675,000,000

637,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

185,000,000

'

Amount of bonds defeased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

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'

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'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

257,000,000

Amount delivered to fund irrevocable trust

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

284,000,000

Unamortized premium and discount

$14,000,000

$23,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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'

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'

'

'

'

LongTerm_Debt_Based_on_Stated_

Long-Term Debt (Based on Stated Maturity Dates Rather than Early Redemption Dates that Could be Elected by Instrument Holders) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'
2014	$1,505
2015	960
2016	1,771
2017	1,378
2018	1,350
Thereafter	13,878
Total	20,842
Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
2014	58
2015	211
2016	476
2017	679
2018	850
Thereafter	5,769
Total	8,043
2014	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	2.95%
2014 | Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.10%
2015	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.45%
2015 | Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	5.39%
2016	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	3.51%
2016 | Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	5.25%
2017	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.55%
2017 | Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	5.44%
2018	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.99%
2018 | Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.17%
Thereafter	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.90%
Thereafter | Virginia Electric and Power Company	'
Debt Instrument [Line Items]	'
Weighted-average Coupon	4.78%
Unsecured Senior Notes	'
Debt Instrument [Line Items]	'
2014	1,465
2015	960
2016	1,752
2017	1,303
2018	1,350
Thereafter	10,523
Total	17,353
Tax-Exempt Financings	'
Debt Instrument [Line Items]	'
2014	40
2015	0
2016	19
2017	75
2018	0
Thereafter	880
Total	1,014
Unsecured Junior Subordinated Notes Payable to Affiliated Trusts	'
Debt Instrument [Line Items]	'
2014	0
2015	0
2016	0
2017	0
2018	0
Thereafter	10
Total	10
Enhanced Junior Subordinated Notes	'
Debt Instrument [Line Items]	'
2014	0
2015	0
2016	0
2017	0
2018	0
Thereafter	1,365
Total	1,365
Remarketable Subordinated Notes	'
Debt Instrument [Line Items]	'
2014	0
2015	0
2016	0
2017	0
2018	0
Thereafter	1,100
Total	$1,100

LongTerm_Debt_Trust_Preferred_

Long-Term Debt (Trust Preferred Securities and Junior Subordinated Notes Outstanding) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2013	Dec. 31, 2013
Share data in Thousands, unless otherwise specified					Jan-01	8.4% Debentures due 1/15/2031
					Dominion Resources Capital Trust III
Debt Instrument [Line Items]	'		'		'	'
Date Established	'		'		'January 2001	'
Units	'		'		10	'
Rate	'		'		8.40%	'
Capital Securities Amount	'		'		$10,000,000	'
Common Securities Amount	5,783,000,000	[1]	5,493,000,000	[1]	300,000	'
Junior subordinated notes	'		'		'	$10,000,000
RSN Annual Interest Rate	'		'		'	8.40%
Debt instrument maturity date	'		'		'	15-Jan-31
[1]	1 billion shares authorized; 581 million shares and 576 million shares outstanding at December 31, 2013 and 2012, respectively.

LongTerm_Debt_Long_Term_Debt_S

Long-Term Debt Long Term Debt (Schedule of Equity Units) (Details) (USD $)	12 Months Ended		0 Months Ended				0 Months Ended
Share data in Millions, unless otherwise specified	Dec. 31, 2013		Jun. 07, 2013		Sep. 30, 2013	Jun. 07, 2013	Jun. 07, 2013		Sep. 30, 2013	Jun. 07, 2013
			Capital Unit, Class A		Capital Unit, Class A	Capital Unit, Class A	Capital Unit, Class B		Capital Unit, Class B	Capital Unit, Class B
					Remarketable Subordinated Notes	Remarketable Subordinated Notes			Remarketable Subordinated Notes	Remarketable Subordinated Notes
Capital Unit [Line Items]	'		'		'	'	'		'	'
Units Issued	'		0		'	'	0		'	'
Total Net Proceeds	'		$533,500,000		'	'	$553,500,000		'	'
Total Long-term Debt	'		'		'	550,000,000	'		'	550,000,000
RSN Annual Interest Rate	'		'		1.07%	'	'		1.18%	'
Stock Purchase Contract Annual Rate	'		5.06%		'	'	4.82%		'	'
Stock Purchase Contract Liability	139,000,000	[1]	76,700,000	[1]	'	'	79,300,000	[1]	'	'
Total payments	$17,000,000		'		'	'	'		'	'
[1]	Payments of $17 million were made in 2013. The stock purchase contract liability was $139 million at December 31, 2013.

Preferred_Stock_Narrative_Deta

Preferred Stock (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Class of Stock [Line Items]	'	'
Preferred stock shares authorized	20,000,000	'
Preferred stock shares issued	0	0
Virginia Electric and Power Company	'	'
Class of Stock [Line Items]	'	'
Preferred stock shares authorized	10,000,000	'
Preferred stock shares issued	2,590,000	2,590,000
Preferred stock shares outstanding	2,590,000	2,590,000
Entitled Per Share Upon Liquidation	100	'

Preferred_Stock_Preferred_Stoc

Preferred Stock Preferred Stock (Schedule of Preferred Stock) (Details) (Virginia Electric and Power Company, USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013		Feb. 28, 2014
		$5.00	$4.04	$4.20	$4.12	$4.80	$7.05	$6.98	Flex Money Market Preferred 12/02, Series A		Flex Money Market Preferred 12/02, Series A
											Subsequent Event
Class of Stock [Line Items]	'	'	'	'	'	'	'	'	'		'
Dividend	'	$5	$4.04	$4.20	$4.12	$4.80	$7.05	$6.98	'		'
Issued and Outstanding Shares	2,590	107	13	15	32	73	500	600	1,250		'
Entitled Per Share Upon Liquidation	$100	$112.50	$102.27	$102.50	$103.73	$101	$100	$100	$100	[1]	$100	[1]
Dividend rate	6.12%	'	'	'	'	'	'	'	'		'
[1]	Effective March 20, 2011 the rate was reset to 6.12% until March 20, 2014 after which the rate was due to be reset through an auction process. However, in February 2014, Virginia Power provided irrevocable notice to redeem the stock on March 20, 2014 at a price of $100 per share plus accumulated and unpaid dividends.

Shareholders_Equity_Narrative_

Shareholders' Equity (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Jan. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2007

Feb. 28, 2013

Feb. 28, 2012

Feb. 28, 2011

Feb. 28, 2010

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Agreement

Dominion Direct, Employee Stock Awards, Employee Savings Plans, Director Stock Compensation Plans, and Contingent Convertible Senior Notes

Stock-Based Awards

Restricted Stock

Restricted Stock

Restricted Stock

Goal-Based Stock

Goal-Based Stock

Goal-Based Stock

Cash-Based Performance Grant

Cash-Based Performance Grant

Cash-Based Performance Grant

February 2011 Awards

February 2011 Awards

February 2011 Awards

February 2011 Awards

February 2012 Awards

February 2012 Awards

February 2013 Awards

Dominion Direct, employee savings plans

Performance_Metric

Officer

Officer

Performance_Metric

Performance_Metric

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock shares issued

'

5,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,700,000

Cash proceeds

'

$278

$265

$38

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of sales agency agreements

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expected issuance of common stock in 2012 through employee savings plans, direct stock purchase and dividend reinvestment plans, and other employee and director benefit plans

'

317

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares reserved and available for issuance

'

22,500,000

'

'

48,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares were available for future grants

'

'

'

'

'

32,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Compensation cost related to stock-based compensation

'

31

25

39

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Tax benefit from stock awards and stock options exercised

'

11

8

13

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Tax benefits from the vesting of restricted stock awards

'

1

10

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash proceeds from the exercise of stock options

'

'

19

38

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Vesting period

'

'

'

'

'

'

'3 years

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost related to nonvested awards

'

'

'

'

'

'

21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Expected weighted-average period recognized for the unrecognized compensation cost

'

'

'

'

'

'

'1 year 9 months 6 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of restricted stock awards that vested

'

'

'

'

'

'

20

30

28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of performance metrics

'

'

'

'

'

'

'

'

'

2

'

'

2

2

'

'

'

'

'

'

'

'

'

Performance metrics period

'

'

'

'

'

'

'

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares issued minimum percentage

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares issued maximum percentage

'

'

'

'

'

'

'

'

'

200.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock awards granted

'

'

'

'

'

'

'

'

'

'

3,000

9,000

'

'

'

'

'

'

'

'

'

'

'

Number of shares converted to one class to another

'

'

'

'

'

'

'

'

168,000

1,000

2,000

15,000

'

'

'

'

'

'

'

'

'

'

'

Targeted shares expected to be issued

'

'

'

'

'

'

'

'

'

5,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash-based performance grants minimum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

'

'

'

'

Cash-based performance grants maximum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200.00%

'

'

'

'

'

'

'

'

Cash based performance grant actual payout

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

6

6

14

8

'

'

'

Cash-based performance grants

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8

20

'

'

'

'

13

'

Cash based performance grant liability accrued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

6

'

Cash based performance grants, total expected award

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$12

'

'

Shareholders_Equity_Accumulate

Shareholders' Equity (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'
Net unrealized losses on derivatives-hedging activities, net of tax	($288)	($122)
Net unrealized gains on nuclear decommissioning trust funds, net of tax	474	326
Net unrecognized pension and other postretirement benefit costs, net of tax	-510	-1,081
Total AOCI	-324	-877
Net unrealized gains on derivatives-hedging activities, tax	-196	-87
Net unrealized gains on nuclear decommissioning trust funds, tax	307	206
Net unrecognized pension and other postretirement benefit costs, tax	-365	-745
Virginia Electric and Power Company	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'
Net unrealized losses on derivatives-hedging activities, net of tax	0	-6
Net unrealized gains on nuclear decommissioning trust funds, net of tax	48	31
Total AOCI	48	25
Net unrealized gains on derivatives-hedging activities, tax	0	-3
Net unrecognized pension and other postretirement benefit costs, tax	$30	$19

Shareholders_Equity_Schedule_o

Shareholders' Equity (Schedule of Components of Accumulated Other Comprehensive Income) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	($877)		'	'
Other comprehensive income before reclassifications: gains (losses)	476		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	77	[1]	'	'
Total other comprehensive income income (loss)	553		-267	-280
Ending balance	-324		-877	'
Deferred gains and losses on derivatives-hedging activities	'		'	'
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	-122		'	'
Other comprehensive income before reclassifications: gains (losses)	-243		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	77	[1]	'	'
Total other comprehensive income income (loss)	-166		'	'
Ending balance	-288		'	'
Unrealized gains and losses on investment securities	'		'	'
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	326		'	'
Other comprehensive income before reclassifications: gains (losses)	203		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-55	[1]	'	'
Total other comprehensive income income (loss)	148		'	'
Ending balance	474		'	'
Unrecognized pension and other postretirement benefit costs	'		'	'
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	-1,081		'	'
Other comprehensive income before reclassifications: gains (losses)	516		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	55	[1]	'	'
Total other comprehensive income income (loss)	571		'	'
Ending balance	-510		'	'
Virginia Electric and Power Company	'		'	'
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	25		'	'
Other comprehensive income before reclassifications: gains (losses)	26		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-3	[1]	'	'
Total other comprehensive income income (loss)	23		6	-5
Ending balance	48		25	'
Virginia Electric and Power Company | Deferred gains and losses on derivatives-hedging activities	'		'	'
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	-6		'	'
Other comprehensive income before reclassifications: gains (losses)	6		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	0	[1]	'	'
Total other comprehensive income income (loss)	6		'	'
Ending balance	0		'	'
Virginia Electric and Power Company | Unrealized gains and losses on investment securities	'		'	'
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'		'	'
Beginning balance	31		'	'
Other comprehensive income before reclassifications: gains (losses)	20		'	'
Amounts reclassified from accumulated other comprehensive income: (gains) losses	-3	[1]	'	'
Total other comprehensive income income (loss)	17		'	'
Ending balance	$48		'	'
[1]	See table below for details about these reclassifications.

Shareholders_Equity_Schedule_o1

Shareholders' Equity (Schedule of Reclassifications out of Accumulated Other Comprehensive Income) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

'

'

'

'

'

'

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Operating Revenue

$3,185

[1]

$3,432

$2,980

$3,523

$3,101

$3,332

$3,005

$3,397

$13,120

$12,835

[2]

$13,765

[2]

Purchased gas

'

'

'

'

'

'

'

'

1,331

1,177

[2]

1,764

[2]

Electric fuel and other energy-related purchases

'

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'

'

'

'

'

'

3,885

3,645

[2]

3,942

[2]

Interest and related charges

'

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'

'

'

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'

'

877

816

[2]

796

[2]

Income from continuing operations including noncontrolling interests before income taxes

'

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'

'

'

2,704

2,265

[2]

2,262

[2]

Income Tax Expense (Benefit)

'

'

'

'

'

'

'

'

-892

[3]

-811

[2],[3]

-778

[2],[3]

Income from continuing operations including noncontrolling interests

'

'

'

'

'

'

'

'

1,812

1,454

[2]

1,484

[2]

Other income

'

'

'

'

'

'

'

'

265

223

[2]

178

[2]

Impairment

'

'

'

'

'

'

'

'

8

14

48

Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income

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Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

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'

Income from continuing operations including noncontrolling interests before income taxes

'

'

'

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130

'

'

Income Tax Expense (Benefit)

'

'

'

'

'

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'

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-53

'

'

Income from continuing operations including noncontrolling interests

'

'

'

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77

'

'

Unrealized gains and losses on investment securities | Reclassification out of Accumulated Other Comprehensive Income

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'

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'

'

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'

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

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'

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'

'

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'

Income from continuing operations including noncontrolling interests before income taxes

'

'

'

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'

-90

'

'

Income Tax Expense (Benefit)

'

'

'

'

'

'

'

'

35

'

'

Income from continuing operations including noncontrolling interests

'

'

'

'

'

'

'

'

-55

'

'

Other income

'

'

'

'

'

'

'

'

-98

'

'

Impairment

'

'

'

'

'

'

'

'

8

'

'

Unrecognized pension and other postretirement benefit costs | Reclassification out of Accumulated Other Comprehensive Income

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'

'

'

'

'

'

'

'

'

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

'

'

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'

'

'

'

'

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'

'

Income from continuing operations including noncontrolling interests before income taxes

'

'

'

'

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'

'

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94

'

'

Income Tax Expense (Benefit)

'

'

'

'

'

'

'

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-39

'

'

Income from continuing operations including noncontrolling interests

'

'

'

'

'

'

'

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55

'

'

Prior-service costs (credits)

'

'

'

'

'

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'

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-8

'

'

Actuarial losses

'

'

'

'

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'

'

102

'

'

Commodity | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income

'

'

'

'

'

'

'

'

'

'

'

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

'

'

'

'

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'

'

Operating Revenue

'

'

'

'

'

'

'

'

58

'

'

Purchased gas

'

'

'

'

'

'

'

'

47

'

'

Electric fuel and other energy-related purchases

'

'

'

'

'

'

'

'

10

'

'

Interest rate | Deferred gains and losses on derivatives-hedging activities | Reclassification out of Accumulated Other Comprehensive Income

'

'

'

'

'

'

'

'

'

'

'

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

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'

Interest and related charges

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15

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Virginia Electric and Power Company

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'

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

'

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Operating Revenue

1,745

2,059

1,710

1,781

1,630

2,086

1,756

1,754

7,295

7,226

7,246

Electric fuel and other energy-related purchases

'

'

'

'

'

'

'

'

2,304

2,368

2,506

Interest and related charges

'

'

'

'

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'

'

'

369

385

331

Income from continuing operations including noncontrolling interests before income taxes

'

'

'

'

'

'

'

'

1,797

1,703

1,362

Income Tax Expense (Benefit)

'

'

'

'

'

'

'

'

-659

[4]

-653

[4]

-540

[4]

Other income

'

'

'

'

'

'

'

'

86

96

88

Impairment

'

'

'

'

'

'

'

'

1

1

4

Virginia Electric and Power Company | Unrealized gains and losses on investment securities | Reclassification out of Accumulated Other Comprehensive Income

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'

Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]

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'

Income from continuing operations including noncontrolling interests before income taxes

'

'

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-5

'

'

Income Tax Expense (Benefit)

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2

'

'

Income from continuing operations including noncontrolling interests

'

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-3

'

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Other income

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-6

'

'

Impairment

'

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$1

'

'

[1]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.

[2]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

[3]

In 2012, Dominion’s current federal income tax expense for continuing and discontinued operations includes a $195 million benefit related to a carryback of its 2012 net operating loss. In 2011, Dominion’s deferred federal income tax expense includes the recognition of a $346 million benefit, including $51 million related to discontinued operations, for its 2011 net operating loss expected to be used to reduce taxable income in future years.

[4]

In 2011, Virginia Power’s deferred federal income tax expense includes a $54 million benefit related to a portion of its 2011 net operating loss that is expected to be used in future years. Also, Virginia Power’s current federal income tax expense reflects the amounts of its 2011 net operating losses realized through its participation in a tax sharing agreement with Dominion and its subsidiaries.

Shareholders_Equity_Summary_of

Shareholders' Equity (Summary of Changes in Amounts of Stock Options Outstanding) (Details) (USD $)	12 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2011	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]	'	'	'
Outstanding and exercisable beginning, Shares	628	'	'
Exercised, Shares	-622	'	-1,174
Forfeited/expired, Shares	-6	'	-8
Outstanding and exercisable ending, Shares	0	1,810	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price [Roll Forward]	'	'	'
Outstanding and exercisable beginning, Weighted-average Exercise Price	$30.81	'	'
Exercised, Weighted-average Exercise Price	$30.79	$32.46	'
Forfeited/expired, Weighted-average Exercise Price	$32.26	$31.57	'
Outstanding and exercisable ending, Weighted-average Exercise Price	$0	$31.76	'
Outstanding and exercisable beginning, Aggregated Intrinsic Value	$14	'	'
Exercised, Aggregated Intrinsic Value	13	'	17
Outstanding and exercisable ending, Aggregated Intrinsic Value	$0	$20	'

Shareholders_Equity_Summary_of1

Shareholders' Equity (Summary of Restricted Stock and Goal-Based Stock Activity) (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Restricted Stock	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]	'	'	'
Nonvested beginning, Shares	1,085	1,301	1,476
Granted, Shares	312	390	299
Vested, Shares	-356	-596	-617
Cancelled and forfeited, Shares	-34	-10	-25
Converted from goal-based stock to restricted stock, Shares	'	'	168
Nonvested ending, Shares	1,007	1,085	1,301
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'
Nonvested beginning, Weighted Average Grant Date Fair Value	$44.46	$37.37	$38.20
Granted, Weighted Average Grant Date Fair Value	$54.70	$51.14	$43.68
Vested, Weighted Average Grant Date Fair Value	$39	$33.31	$40.72
Cancelled and forfeited, Weighted Average Grant Date Fair Value	$51.11	$42.99	$36.29
Converted from goal-based stock to restricted stock, Weighted - average Grant Date Fair Value	'	'	$30.99
Nonvested ending, Weighted Average Grant Date Fair Value	$49.35	$44.46	$37.37
Goal-Based Stock	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]	'	'	'
Nonvested beginning, Shares	4	12	161
Granted, Shares	4	1	3
Vested, Shares	-2	-9	-20
Cancelled and forfeited, Shares	-1	'	-132
Converted from goal-based stock to restricted stock, Shares	1	'	'
Nonvested ending, Shares	5	4	12
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Roll Forward]	'	'	'
Nonvested beginning, Weighted Average Grant Date Fair Value	$45.60	$39.19	$31.79
Granted, Weighted Average Grant Date Fair Value	$54.17	$52.48	$43.54
Vested, Weighted Average Grant Date Fair Value	$43.54	$37.46	$34.62
Cancelled and forfeited, Weighted Average Grant Date Fair Value	$43.54	'	$30.99
Nonvested ending, Weighted Average Grant Date Fair Value	$53.85	$45.60	$39.19

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	3 Months Ended			12 Months Ended
	Dec. 31, 2013		Jun. 30, 2013	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Actual return on plan assets	'		'	$959,000,000		$743,000,000		'
Expected return on pension and other postretirement plan assets	'		'	554,000,000		509,000,000		'
Federal subsidy received	'		'	5,000,000		'		'
Decrease in other postretirement benefit obligations due to federal subsidy	'		'	20,000,000		'		'
Reduction in accumulated postretirement benefit obligation	220,000,000		'	220,000,000		'		'
Reduction in net periodic benefit cost for next year	8,000,000		36,000,000	'		'		'
Period for reduction in net periodic benefit cost	'		'	'5 years		'		'
Accumulated benefit obligation	5,100,000,000		'	5,100,000,000		5,500,000,000		'
Cumulative required contribution period (years)	'		'	'10 years		'		'
Expected contribution to voluntary employees beneficiary association	'		'	12,000,000		'		'
Percentage coverage of US stock market	'		'	7.00%		'		'
Employer contributions	'		'	40,000,000		40,000,000		38,000,000
U.S. equity:	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Defined benefit plan, actual plan asset allocations	28.00%		'	28.00%		'		'
Non-U.S. equity:	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Defined benefit plan, actual plan asset allocations	18.00%		'	18.00%		'		'
Fixed Income	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Defined benefit plan, actual plan asset allocations	33.00%		'	33.00%		'		'
Real estate:	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Defined benefit plan, actual plan asset allocations	3.00%		'	3.00%		'		'
Other alternative investments	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Defined benefit plan, actual plan asset allocations	18.00%		'	18.00%		'		'
Virginia Electric and Power Company	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Employer contributions	'		'	16,000,000		15,000,000		14,000,000
Net periodic benefit cost	'		'	96,000,000		72,000,000		50,000,000
Virginia Electric and Power Company | Dominion Retiree Health And Welfare Plan	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Net periodic benefit cost	'		'	5,000,000		13,000,000		23,000,000
Minimum	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Expected reduction in net periodic benefit cost	'		'	40,000,000		'		'
Investment grade bonds average weighted maturity period	'		'	'4 years		'		'
Maximum	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Expected reduction in net periodic benefit cost	'		'	60,000,000		'		'
Investment grade bonds average weighted maturity period	'		'	'12 years		'		'
Pension Benefits	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Expected return on pension and other postretirement plan assets	'		'	462,000,000		430,000,000		440,000,000
Medicare Part D reimbursement	'		354,000,000	'		'		'
Reduction in accumulated postretirement benefit obligation	-22,000,000	[1]	'	-22,000,000	[1]	0	[1]	0	[1]
Discount rate	'		4.80%	'		'		'
Net periodic benefit cost	'		'	106,000,000		89,000,000		25,000,000
Other Postretirement Benefits	'		'	'		'		'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'		'	'		'		'
Expected return on pension and other postretirement plan assets	'		'	92,000,000		79,000,000		79,000,000
Medicare Part D reimbursement	'		78,000,000	'		'		'
Reduction in accumulated postretirement benefit obligation	-7,000,000	[1]	'	-7,000,000	[1]	-2,000,000	[1]	-1,000,000	[1]
Discount rate	4.80%		4.70%	4.80%		'		'
Net periodic benefit cost	'		'	$2,000,000		$33,000,000		$63,000,000
[1]	2013 amount relates primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.

Employee_Benefit_Plans_Pension

Employee Benefit Plans (Pension Plan and Other Postretirement Benefit Plan Obligations and Plan Assets and Includes a Statement of the Plans Funded Status) (Details) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Changes in fair value of plan assets:	'	'		'		'
Actual return on plan assets	'	$959		$743		'
Employer contributions	'	40		40		38
Pension Benefits	'	'		'		'
Changes in benefit obligation:	'	'		'		'
Service cost	'	131		116		108
Interest cost	'	271		268		258
Medicare Part D reimbursement	354	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	4.80%	'		'		'
Other Postretirement Benefits	'	'		'		'
Changes in benefit obligation:	'	'		'		'
Service cost	'	43		44		48
Interest cost	'	73		79		94
Medicare Part D reimbursement	78	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	4.70%	4.80%		'		'
Changes In Benefit Obligation | Pension Benefits	'	'		'		'
Changes in benefit obligation:	'	'		'		'
Benefit obligation at beginning of year	'	6,125		4,981		'
Service cost	'	131		116		'
Interest cost	'	271		268		'
Benefits paid	'	-229		-208		'
Actuarial (gains) losses during the year	'	-650		967		'
Plan amendments	'	1	[1]	1	[1]	'
Settlements and curtailments	'	-24	[2]	0	[2]	'
Special termination benefits	'	0		0		'
Medicare Part D reimbursement	'	0		0		'
Benefit obligation at end of year	'	5,625		6,125		'
Changes In Benefit Obligation | Other Postretirement Benefits	'	'		'		'
Changes in benefit obligation:	'	'		'		'
Benefit obligation at beginning of year	'	1,719		1,493		'
Service cost	'	43		44		'
Interest cost	'	73		79		'
Benefits paid	'	-75		-88		'
Actuarial (gains) losses during the year	'	-170		191		'
Plan amendments	'	-220	[1]	1	[1]	'
Settlements and curtailments	'	-16	[2]	-6	[2]	'
Special termination benefits	'	1		0		'
Medicare Part D reimbursement	'	5		5		'
Benefit obligation at end of year	'	1,360		1,719		'
Changes In Fair Value Of Plan Assets | Pension Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Fair value of plan assets at beginning of year	'	5,553		5,145		'
Actual return on plan assets	'	781		611		'
Employer contributions	'	8		5		'
Benefits paid	'	-229		-208		'
Fair value of plan assets at end of year	'	6,113		5,553		'
Funded status at end of year	'	488		-572		'
Changes In Fair Value Of Plan Assets | Other Postretirement Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Fair value of plan assets at beginning of year	'	1,156		1,042		'
Actual return on plan assets	'	178		132		'
Employer contributions	'	12		16		'
Benefits paid	'	-31		-34		'
Fair value of plan assets at end of year	'	1,315		1,156		'
Funded status at end of year	'	-45		-563		'
Level 1 | Pension Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Noncurrent pension and other postretirement benefit assets	'	913		701		'
Other current liabilities	'	-15		-2		'
Noncurrent pension and other postretirement benefit liabilities	'	-410		-1,271		'
Net amount recognized	'	488		-572		'
Level 1 | Other Postretirement Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Noncurrent pension and other postretirement benefit assets	'	29		1		'
Other current liabilities	'	-3		-4		'
Noncurrent pension and other postretirement benefit liabilities	'	-71		-560		'
Net amount recognized	'	($45)		($563)		'
Level 2 | Pension Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	'	'		4.40%	[3]	'
Weighted average rate of increase for compensation	'	4.21%		4.21%		'
Level 2 | Other Postretirement Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	'	'		4.40%	[3]	'
Weighted average rate of increase for compensation	'	4.22%		4.22%		'
Minimum | Level 2 | Pension Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	'	5.20%	[3]	'		'
Minimum | Level 2 | Other Postretirement Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	'	5.00%	[3]	'		'
Maximum | Level 2 | Pension Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	'	5.30%	[3]	'		'
Maximum | Level 2 | Other Postretirement Benefits	'	'		'		'
Changes in fair value of plan assets:	'	'		'		'
Discount rate	'	5.10%	[3]	'		'
[1]	Relates to a plan amendment that changed medical coverage for certain Medicare-eligible retirees.
[2]	2013 amounts relate primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.
[3]	Pension rates are 5.20% for the gas union plans and 5.30% for the nonunion and other union plans. OPEB rates are 5.00% for the gas union plans and 5.10% for the nonunion and other union plans.

Employee_Benefit_Plans_Benefit

Employee Benefit Plans (Benefit Obligation in Excess of Plan Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Pension Benefits	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Benefit obligation	$4,978	$5,462
Fair value of plan assets	4,553	4,189
Other Postretirement Plans	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Benefit obligation	1,233	1,591
Fair value of plan assets	$1,158	$1,027

Employee_Benefit_Plans_Accumul

Employee Benefit Plans (Accumulated Benefit Obligation in Excess of Plan Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
General Discussion of Pension and Other Postretirement Benefits [Abstract]	'	'
Accumulated benefit obligation	$114	$4,850
Fair value of plan assets	$0	$4,189

Employee_Benefit_Plans_Benefit1

Employee Benefit Plans (Benefit Payments Expected Future Service) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Pension Benefits	'
Defined Benefit Plan Disclosure [Line Items]	'
2014	$264
2015	269
2016	283
2017	300
2018	319
2019-2023	1,868
Other Postretirement Plans	'
Defined Benefit Plan Disclosure [Line Items]	'
2014	91
2015	93
2016	96
2017	98
2018	100
2019-2023	$507

Employee_Benefit_Plans_Fair_va

Employee Benefit Plans (Fair values of pension and post retirement plan assets by asset category) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Pension Benefits	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	$6,113	$5,553
Pension Benefits | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	179	195
Pension Benefits | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	1,220	1,031
Pension Benefits | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	514	524
Pension Benefits | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	308	381
Pension Benefits | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	391	395
Pension Benefits | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	1,387	0
Pension Benefits | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	494	1,053
Pension Benefits | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	231	635
Pension Benefits | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	176	72
Pension Benefits | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	57	48
Pension Benefits | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	32	29
Pension Benefits | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	227	321
Pension Benefits | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	530	456
Pension Benefits | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	180	192
Pension Benefits | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	187	221
Pension Benefits | Level 1	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	2,639	2,286
Pension Benefits | Level 1 | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	53	0
Pension Benefits | Level 1 | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	1,220	927
Pension Benefits | Level 1 | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	514	425
Pension Benefits | Level 1 | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	308	313
Pension Benefits | Level 1 | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	391	228
Pension Benefits | Level 1 | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 1 | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	43	27
Pension Benefits | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	2	331
Pension Benefits | Level 1 | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	69	1
Pension Benefits | Level 1 | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	7	5
Pension Benefits | Level 1 | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	32	29
Pension Benefits | Level 1 | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 1 | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 1 | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 1 | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 2	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	2,350	2,077
Pension Benefits | Level 2 | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	126	195
Pension Benefits | Level 2 | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	104
Pension Benefits | Level 2 | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	99
Pension Benefits | Level 2 | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	68
Pension Benefits | Level 2 | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	167
Pension Benefits | Level 2 | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	1,387	0
Pension Benefits | Level 2 | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	451	1,026
Pension Benefits | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	229	304
Pension Benefits | Level 2 | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	107	71
Pension Benefits | Level 2 | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	50	43
Pension Benefits | Level 2 | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 2 | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 2 | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 2 | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 2 | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	1,124	1,190
Pension Benefits | Level 3 | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Pension Benefits | Level 3 | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	227	321
Pension Benefits | Level 3 | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	530	456
Pension Benefits | Level 3 | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	180	192
Pension Benefits | Level 3 | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	187	221
Other Postretirement Plans	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	1,315	1,156
Other Postretirement Plans | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	17	13
Other Postretirement Plans | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	472	383
Other Postretirement Plans | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	26	66
Other Postretirement Plans | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	111	96
Other Postretirement Plans | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	20	19
Other Postretirement Plans | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	502	0
Other Postretirement Plans | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	25	161
Other Postretirement Plans | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	12	282
Other Postretirement Plans | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	9	9
Other Postretirement Plans | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	3	2
Other Postretirement Plans | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	2	1
Other Postretirement Plans | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	19	24
Other Postretirement Plans | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	60	58
Other Postretirement Plans | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	27	31
Other Postretirement Plans | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	10	11
Other Postretirement Plans | Level 1	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	640	521
Other Postretirement Plans | Level 1 | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	3	0
Other Postretirement Plans | Level 1 | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	472	378
Other Postretirement Plans | Level 1 | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	26	21
Other Postretirement Plans | Level 1 | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	111	93
Other Postretirement Plans | Level 1 | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	20	11
Other Postretirement Plans | Level 1 | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 1 | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	2	1
Other Postretirement Plans | Level 1 | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	16
Other Postretirement Plans | Level 1 | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	4	0
Other Postretirement Plans | Level 1 | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 1 | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	2	1
Other Postretirement Plans | Level 1 | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 1 | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 1 | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 1 | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 2	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	559	511
Other Postretirement Plans | Level 2 | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	14	13
Other Postretirement Plans | Level 2 | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	5
Other Postretirement Plans | Level 2 | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	45
Other Postretirement Plans | Level 2 | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	3
Other Postretirement Plans | Level 2 | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	8
Other Postretirement Plans | Level 2 | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	502	0
Other Postretirement Plans | Level 2 | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	23	160
Other Postretirement Plans | Level 2 | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	12	266
Other Postretirement Plans | Level 2 | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	5	9
Other Postretirement Plans | Level 2 | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	3	2
Other Postretirement Plans | Level 2 | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 2 | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 2 | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 2 | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 2 | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	116	124
Other Postretirement Plans | Level 3 | Cash equivalents and other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Non-U.S. equity: | Large Cap	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Non-U.S. equity: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Common/collective trust funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Fixed Income: | Corporate debt instruments	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Fixed Income: | U.S. Treasury securities and agency debentures	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Fixed Income: | State and municipal	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Fixed Income: | Other	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Real estate: | REITs	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	0	0
Other Postretirement Plans | Level 3 | Real estate: | Partnerships	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	19	24
Other Postretirement Plans | Level 3 | Other alternative investments: | Private equity	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	60	58
Other Postretirement Plans | Level 3 | Other alternative investments: | Debt	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	27	31
Other Postretirement Plans | Level 3 | Other alternative investments: | Hedge funds	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Pension plan assets by asset category	$10	$11

Employee_Benefit_Plans_Pension1

Employee Benefit Plans (Pension plan and other postretirement plan assets that are measured at fair value and included in the Level 3 fair value category) (Details) (Level 3, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	$1,190	$1,285	$1,278
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	166	105	128
Relating to assets sold during the period	-122	-62	-67
Purchases	153	129	215
Sales	-263	-267	-269
Fair value of plan assets at end of year	1,124	1,190	1,285
Pension Benefits | Real estate:	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	321	304	271
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	15	21	38
Relating to assets sold during the period	-36	-8	-8
Purchases	6	35	57
Sales	-79	-31	-54
Fair value of plan assets at end of year	227	321	304
Pension Benefits | Private equity	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	456	448	400
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	98	46	70
Relating to assets sold during the period	-48	-41	-34
Purchases	115	79	76
Sales	-91	-76	-64
Fair value of plan assets at end of year	530	456	448
Pension Benefits | Debt	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	192	243	262
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	32	17	10
Relating to assets sold during the period	-34	-11	-10
Purchases	32	15	34
Sales	-42	-72	-53
Fair value of plan assets at end of year	180	192	243
Pension Benefits | Hedge funds	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	221	290	345
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	21	21	10
Relating to assets sold during the period	-4	-2	-15
Purchases	0	0	48
Sales	-51	-88	-98
Fair value of plan assets at end of year	187	221	290
Other Postretirement Plans	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	124	137	140
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	8	9	15
Relating to assets sold during the period	5	-1	-6
Purchases	10	9	16
Sales	-31	-30	-28
Fair value of plan assets at end of year	116	124	137
Other Postretirement Plans | Real estate:	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	24	24	22
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	-2	1	3
Relating to assets sold during the period	1	0	0
Purchases	1	2	3
Sales	-5	-3	-4
Fair value of plan assets at end of year	19	24	24
Other Postretirement Plans | Private equity	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	58	63	61
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	6	3	11
Relating to assets sold during the period	3	-1	-4
Purchases	7	6	8
Sales	-14	-13	-13
Fair value of plan assets at end of year	60	58	63
Other Postretirement Plans | Debt	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	31	36	40
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	3	4	1
Relating to assets sold during the period	0	0	-1
Purchases	2	1	3
Sales	-9	-10	-7
Fair value of plan assets at end of year	27	31	36
Other Postretirement Plans | Hedge funds	'	'	'
Changes in fair value of plan assets:	'	'	'
Fair value of plan assets at beginning of year	11	14	17
Actual return on plan assets:	'	'	'
Relating to assets still held at the reporting date	1	1	0
Relating to assets sold during the period	1	0	-1
Purchases	0	0	2
Sales	-3	-4	-4
Fair value of plan assets at end of year	$10	$11	$14

Employee_Benefit_Plans_Net_Per

Employee Benefit Plans (Net Periodic Benefit (Credit) Cost and Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Expected return on plan assets	($554)		($509)		'
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:	'		'		'
Settlements and curtailments	220		'		'
Pension Benefits	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Service cost	131		116		108
Interest cost	271		268		258
Expected return on plan assets	-462		-430		-440
Amortization of prior service (credit) cost	3		3		3
Amortization of net actuarial loss	165		132		96
Settlements and curtailments	-2	[1]	0	[1]	0	[1]
Special termination benefits	0		0		0
Net periodic benefit cost	106		89		25
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:	'		'		'
Current year net actuarial (gain) loss	-968		786		534
Prior service (credit) cost	1		0		0
Settlements and curtailments	-22	[1]	0	[1]	0	[1]
Amortization of net actuarial loss	165		132		96
Amortization of prior service credit (cost)	-3		-3		-3
Total recognized in other comprehensive income and regulatory assets and liabilities	-1,157		651		435
Significant assumptions used to determine periodic cost:	'		'		'
Discount rate	'		5.50%		5.90%
Expected long-term rate of return on plan assets	8.50%		8.50%		8.50%
Weighted average rate of increase for compensation	4.21%		4.21%		4.61%
Other Postretirement Plans	'		'		'
Defined Benefit Plan Disclosure [Line Items]	'		'		'
Service cost	43		44		48
Interest cost	73		79		94
Expected return on plan assets	-92		-79		-79
Amortization of prior service (credit) cost	-15		-13		-13
Amortization of net actuarial loss	7		6		12
Settlements and curtailments	-15	[1]	-4	[1]	1	[1]
Special termination benefits	-1		'		0
Net periodic benefit cost	2		33		63
Changes in plan assets and benefit obligations recognized in other comprehensive income and regulatory assets and liabilities:	'		'		'
Current year net actuarial (gain) loss	-255		139		-157
Prior service (credit) cost	-215		1		-70
Settlements and curtailments	-7	[1]	-2	[1]	-1	[1]
Amortization of net actuarial loss	7		6		12
Amortization of prior service credit (cost)	15		13		13
Total recognized in other comprehensive income and regulatory assets and liabilities	($469)		$145		($227)
Significant assumptions used to determine periodic cost:	'		'		'
Discount rate	'		5.50%		5.90%
Expected long-term rate of return on plan assets	7.75%		7.75%		7.75%
Weighted average rate of increase for compensation	4.22%		4.22%		4.62%
Healthcare cost trend rate	7.00%	[2]	7.00%	[2]	7.00%	[2]
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate)	4.60%	[2]	4.60%	[2]	4.60%	[2]
Year that the rate reaches the ultimate trend rate	'2062	[2]	'2061	[2]	'2060	[2]
Minimum | Pension Benefits	'		'		'
Significant assumptions used to determine periodic cost:	'		'		'
Discount rate	4.40%		'		'
Minimum | Other Postretirement Plans	'		'		'
Significant assumptions used to determine periodic cost:	'		'		'
Discount rate	4.40%		'		'
Maximum | Pension Benefits	'		'		'
Significant assumptions used to determine periodic cost:	'		'		'
Discount rate	4.80%		'		'
Maximum | Other Postretirement Plans	'		'		'
Significant assumptions used to determine periodic cost:	'		'		'
Discount rate	4.80%		'		'
[1]	2013 amount relates primarily to the decommissioning of Kewaunee. 2012 amount relates to the sale of Salem Harbor.
[2]	Assumptions used to determine periodic cost for the following year.

Employee_Benefit_Plans_AOCI_an

Employee Benefit Plans (AOCI and regulatory assets and liabilities that have not been recognized as components of periodic benefit (credit) cost) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]	'		'
Net actuarial (gain) loss	($324)		($877)
Pension Benefits	'		'
Defined Benefit Plan Disclosure [Line Items]	'		'
Net actuarial (gain) loss	1,709		2,865
Prior service (credit) cost	10		11
Total	1,719	[1]	2,876	[1]
Related expenses	1,700		2,900
Amount included in AOCI	1,000		1,800
Other Postretirement Plans	'		'
Defined Benefit Plan Disclosure [Line Items]	'		'
Net actuarial (gain) loss	-40		229
Prior service (credit) cost	-271		-71
Total	-311	[1]	158	[1]
Related expenses	-311		158
Amount included in AOCI	($156)		$69
[1]	As of December 31, 2013, of the $1.7 billion and $(311) million related to pension benefits and other postretirement benefits, $1.0 billion and $(156) million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities. As of December 31, 2012, of the $2.9 billion and $158 million related to pension benefits and other postretirement benefits, $1.8 billion and $69 million, respectively, are included in AOCI, with the remainder included in regulatory assets and liabilities.

Employee_Benefit_Plans_Compone

Employee Benefit Plans (Components of AOCI and Regulatory Assets and Liabilities) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefits	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Net actuarial loss	($165)	($132)	($96)
Prior service (credit) cost	-3	-3	-3
Pension Benefits | Scenario, Forecast	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Net actuarial loss	112	'	'
Prior service (credit) cost	3	'	'
Other Postretirement Plans	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Net actuarial loss	-7	-6	-12
Prior service (credit) cost	15	13	13
Other Postretirement Plans | Scenario, Forecast	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Net actuarial loss	2	'	'
Prior service (credit) cost	($28)	'	'

Employee_Benefit_Plans_Effect_

Employee Benefit Plans (Effect of One Percentage Point Change on Benefit Plans) (Details) (Other Postretirement Plans, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Other Postretirement Plans	'
Defined Benefit Plan Disclosure [Line Items]	'
Effect of one percentage point increase on total of service and interest cost components	$16
Effect of one percentage point increase on other postretirement benefit obligation	140
Effect of one percentage point decrease on total of service and interest cost components	-18
Effect of one percentage point decrease on other postretirement benefit obligation	($118)

Commitments_and_Contingencies_1

Commitments and Contingencies (Environmental Matters) (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

3 Months Ended

Jun. 30, 2013

Feb. 28, 2013

Apr. 30, 2012

Sep. 30, 2011

Dec. 31, 2013

Dec. 31, 2012

Jul. 31, 2011

Dec. 31, 2013

Apr. 25, 2013

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

T

MW

Party

Site

T

Clean Air Act

Clean Air Act

Clean Air Act

Remedial options

Virginia Electric and Power Company

Virginia Electric and Power Company

Group

Site

MW

State

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Charge reflecting plant balances not expected to be recovered

'

'

'

'

'

'

'

'

'

'

$228,000,000

$26,000,000

Charge reflecting plant balances not expected to be recovered, net of tax

'

'

'

'

'

'

'

'

'

'

139,000,000

16,000,000

Number of states under EPA Replacement Rule

'

'

'

'

'

'

28

'

'

'

'

'

Emissions of fossil fuel fired electric generating units

'

'

25

'

'

'

25

'

'

'

'

'

Number of groups of affected states

'

'

'

'

'

'

2

'

'

'

'

'

Estimate of possible loss

'

'

'

'

'

'

'

13,000,000

3,000,000

'

'

'

Amount of environmental mitigation projects

'

'

'

'

'

'

'

'

10,000,000

'

'

'

Number of parties ordered specific remedial action

'

'

'

22

'

'

'

'

'

'

'

'

Maximum civil penalties per day

'

'

'

'

37,500

'

'

'

'

'

'

'

Number of former manufactured gas plant sites

'

'

'

'

17

'

'

'

'

'

'

3

Preliminary costs for options under evaluation for the site, minimum

'

'

'

'

'

'

'

'

'

1,000,000

'

'

Preliminary costs for options under evaluation for the site, maximum

'

'

'

'

'

'

'

'

'

$22,000,000

'

'

Percentage Reduction In CO2 Emissions

'

10.00%

'

'

'

'

'

'

'

'

'

'

CO2 Emissions Cap

'

91,000,000

'

'

'

165,000,000

'

'

'

'

'

'

Percent further emission reduction goals in participating state power plant CO2 emissions

'

'

'

'

2.50%

'

'

'

'

'

'

'

National GHC reduction goal, percentage

17.00%

'

'

'

'

'

'

'

'

'

'

'

Period for consideration of CO2 emissions for biomass projects

'

'

'

'

'3 years

'

'

'

'

'

'

'

Commitments_and_Contingencies_2

Commitments and Contingencies (MF Global) (Details) (MF Global Bankruptcy, USD $)	1 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jan. 31, 2013	Dec. 31, 2013	Oct. 31, 2011
MF Global Bankruptcy	'	'	'
Loss Contingencies [Line Items]	'	'	'
Initial margin posted	'	'	$73
Margin received to date	'	17	'
Remaining margin claims sold to 3rd party	$56	'	'

Commitments_and_Contingencies_3

Commitments and Contingencies (Nuclear Operations) (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

Nov. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Spent Nuclear Fuel

Spent Nuclear Fuel

Millstone Unit 1

Kewaunee

Kewaunee

Millstone

Millstone

Nuclear Plant

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Virginia Electric and Power Company

Spent Nuclear Fuel

Spent Nuclear Fuel

Kewaunee

Surry and North Anna

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Coverage that exceeds NRC minimum requirement

'

$1,060,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum financial assurance

'

'

'

'

2,800,000,000

'

'

'

'

'

'

'

'

1,800,000,000

'

Liability protection under Price-Anderson Act

'

'

'

'

'

'

'

'

'

13,600,000,000

'

'

'

'

'

Amount of coverage purchased from commercial insurance pools

'

375,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount that could be assessed for each licensed reactor

'

127,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount that could be assessed for each licensed reactor per reactor

'

19,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum assessment for premiums on insurance policy

'

71,000,000

'

'

'

'

'

'

'

'

39,000,000

'

'

'

'

Maximum assessment for insurance policy

'

19,000,000

'

'

'

'

'

'

'

'

9,000,000

'

'

'

'

Payments for legal settlements

'

'

'

'

'

'

6,000,000

5,000,000

20,000,000

'

'

'

'

'

75,000,000

Litigation Settlement, Amount

'

'

'

'

'

2,000,000

'

'

'

'

'

'

'

'

'

Receivables

'

'

79,000,000

36,000,000

'

'

'

'

'

'

'

50,000,000

26,000,000

'

'

Current fee per kWh for electricity paid by civilian nuclear power generators

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Waste fee recognized

'

$44,000,000

'

'

'

'

'

'

'

'

$27,000,000

'

'

'

'

Commitments_and_Contingencies_4

Commitments and Contingencies (Nuclear Insurance) (Details) (USD $)	Dec. 31, 2013
Millstone	'
Guarantor Obligations [Line Items]	'
Property insurance coverage	$1,700,000
Kewaunee	'
Guarantor Obligations [Line Items]	'
Property insurance coverage	1,060,000
Surry | Virginia Electric and Power Company	'
Guarantor Obligations [Line Items]	'
Property insurance coverage	1,700,000	[1]
North Anna | Virginia Electric and Power Company	'
Guarantor Obligations [Line Items]	'
Property insurance coverage	1,700,000	[1]
Surry and North Anna	'
Guarantor Obligations [Line Items]	'
Coverage amount	$450,000,000
[1]	Surry and North Anna share a blanket property limit of $450 million.

Commitment_and_Contingencies_S

Commitment and Contingencies (Schedule of Long Term Purchase Commitments) (Details) (Virginia Electric and Power Company, USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Long-term Purchase Commitment [Line Items]	'		'	'
Present value of total commitment for capacity payments	$1,100,000,000		'	'
Purchased electric capacity	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
2014	336,000,000	[1]	'	'
2015	316,000,000	[1]	'	'
2016	253,000,000	[1]	'	'
2017	159,000,000	[1]	'	'
2018	104,000,000	[1]	'	'
Thereafter	163,000,000	[1]	'	'
Total	1,331,000,000	[1]	'	'
Payments	345,000,000		337,000,000	338,000,000
Energy payments	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Payments	$236,000,000		$214,000,000	$275,000,000
[1]	Commitments represent estimated amounts payable for capacity under power purchase contracts with qualifying facilities and independent power producers, the last of which ends in 2021. Capacity payments under the contracts are generally based on fixed dollar amounts per month, subject to escalation using broad-based economic indices. At December 31, 2013, the present value of Virginia Power's total commitment for capacity payments is $1.1 billion. Capacity payments totaled $345 million, $337 million, and $338 million, and energy payments totaled $236 million, $214 million, and $275 million for 2013, 2012 and 2011, respectively.

Commitments_and_Contingencies_5

Commitments and Contingencies (Lease Commitments) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Loss Contingencies [Line Items]	'
2014	$63
2015	60
2016	51
2017	43
2018	37
Thereafter	87
Total	341
Virginia Electric and Power Company	'
Loss Contingencies [Line Items]	'
2014	27
2015	26
2016	21
2017	17
2018	14
Thereafter	27
Total	$132

Commitments_and_Contingencies_6

Commitments and Contingencies (Lease Commitments) (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Loss Contingencies [Line Items]	'	'	'
Rental expense	$101	$112	$155
Virginia Electric and Power Company	'	'	'
Loss Contingencies [Line Items]	'	'	'
Rental expense	$42	$48	$50

Commitments_and_Contingencies_7

Commitments and Contingencies (Guarantees, Surety Bonds and Letters of Credit) (Narrative) (Details) (USD $)	Dec. 31, 2013
Guarantor Obligations [Line Items]	'
Exposure under guarantees	$4,421,000,000
Purchased surety bonds	147,000,000
Standby Letters of Credit	'
Guarantor Obligations [Line Items]	'
Authorized standby letters of credit with financial institutions	11,000,000
Minimum	'
Guarantor Obligations [Line Items]	'
Annual future contributions	4,000,000
Maximum	'
Guarantor Obligations [Line Items]	'
Annual future contributions	19,000,000
Third Party and Equity Method Investee	'
Guarantor Obligations [Line Items]	'
Estimate of possible loss	69,000,000
Exposure under guarantees	39,000,000
Third Party and Equity Method Investee | Through 2019	'
Guarantor Obligations [Line Items]	'
Exposure under guarantees	90,000,000
Virginia Electric and Power Company	'
Guarantor Obligations [Line Items]	'
Purchased Surety Bonds	59,000,000
Authorized issuance of standby letters of credit	1,000,000
Virginia Electric and Power Company | Tax-Exempt Financings	'
Guarantor Obligations [Line Items]	'
Estimate of possible loss	$14,000,000

Commitments_and_Contingencies_8

Commitments and Contingencies (Subsidiary Guarantees) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Guarantor Obligations [Line Items]	'
Stated Limit	$4,421
Value	606	[1]
Debt	'
Guarantor Obligations [Line Items]	'
Stated Limit	27	[2]
Value	27	[1],[2]
Commodity transactions	'
Guarantor Obligations [Line Items]	'
Stated Limit	3,158	[2]
Value	403	[1],[2]
Nuclear obligations	'
Guarantor Obligations [Line Items]	'
Stated Limit	232	[3]
Value	68	[1],[3]
Other	'
Guarantor Obligations [Line Items]	'
Stated Limit	669	[4]
Value	108	[1],[4]
Cove Point | Nuclear obligations	'
Guarantor Obligations [Line Items]	'
Stated Limit	335	[5]
Value	0	[1],[5]
Millstone | Nuclear obligations	'
Guarantor Obligations [Line Items]	'
Stated Limit	150
Kewaunee | Nuclear obligations	'
Guarantor Obligations [Line Items]	'
Stated Limit	$60
[1]	Represents the estimated portion of the guarantee's stated limit that is utilized as of December 31, 2013 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 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 and Kewaunee, respectively, in the event of a prolonged outage, as part of satisfying certain NRC requirements concerned with ensuring adequate funding for the operations of nuclear power stations. The agreement for Kewaunee also provides for funds through the completion of decommissioning.
[4]	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.
[5]	Guarantees related to Cove Point, including agreements to support terminal service and transportation agreements as well as an engineering, procurement and construction contract for new liquefaction facilities. Includes certain guarantees that do not have stated limits.

Credit_Risk_Narrative_Details

Credit Risk (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Concentration Risk [Line Items]	'	'
Gross credit exposure	$263	'
Additional collateral to be posted if the credit-related contingent features were triggered	146	110
Collateral already posted	76	4
Fair value of all derivative instruments not fully collateralized	$169	$163
Investment Grade | Investment Grade Counterparties	'	'
Concentration Risk [Line Items]	'	'
Concentration of credit risk	63.00%	'
Investment Grade | CounterpartyA	'	'
Concentration Risk [Line Items]	'	'
Concentration of credit risk	6.00%	'

Related_Party_Transactions_Det

Related Party Transactions (Details) (Virginia Electric and Power Company, USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'	'
Commodity purchases from affiliates	'	$417	$368	$376
Services provided by affiliates	'	415	399	393
Services provided to affiliates	'	21	19	21
Purchased nuclear fuel-related inventory	39	'	'	'
Outstanding borrowings, net of repayments, under the Dominion money pool for Virginia Power's nonregulated subsidiaries	'	'	192	'
Dominion	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Short term demand note borrowings	'	$97	$243	'

Operating_Segments_Narrative_D

Operating Segments (Narrative) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating expenses

'

'

'

'

'

'

'

'

$9,804

$9,977

[1]

$10,885

[1]

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

92

1,125

[1],[2]

58

[1],[2]

Impairment charge

'

'

'

'

'

'

'

'

1,600

'

'

Asset disposition adjustment

'

'

'

'

'

'

'

'

44

11

'

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

92

1,125

[1]

58

[1]

Income from operations

804

[3]

1,034

548

930

761

551

628

918

3,316

2,858

[1]

2,880

[1]

Corporate and Other

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating expenses

'

'

'

'

'

'

'

'

452

1,700

607

Net expenses attributable to other operating segments

'

'

'

'

'

'

'

'

184

1,500

364

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

92

[4]

1,125

[4]

58

[4]

Asset disposition adjustment

'

'

'

'

'

'

'

'

0

[5]

0

[5]

'

Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

0

[4],[6]

0

[4],[6]

0

[4],[6]

Asset disposition adjustment

'

'

'

'

'

'

'

'

19

[7]

0

'

Net gain on investments

'

'

'

'

'

'

'

'

81

'

'

Net gain on investments after tax

'

'

'

'

'

'

'

'

49

'

'

Impairment charge

'

'

'

'

'

'

'

'

'

'

228

Asset impairment, net of tax

'

'

'

'

'

'

'

'

'

'

139

Income from operations

'

'

'

'

'

'

'

'

'

'

-66

Operating income after tax

'

'

'

'

'

'

'

'

'

'

-39

Impairment of emissions allowances

'

'

'

'

'

'

'

'

'

'

43

Impairment of emissions net of taxes

'

'

'

'

'

'

'

'

'

'

26

Dominion Generation | Brayton Point Kincaid And Elwood Power Stations

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Loss before income taxes

'

'

'

'

'

'

'

'

'

1,700

'

Impairment charge

'

'

'

'

1,000

'

'

'

'

'

'

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

'

1,100

'

DVP

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

0

[6]

0

[6]

0

[6]

Asset disposition adjustment

'

'

'

'

'

'

'

'

0

0

'

Charge related to Biennial Review Order

'

'

'

'

'

'

'

'

'

87

96

Restoration costs net of tax

'

'

'

'

'

'

'

'

'

53

59

Dominion Energy

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

0

0

0

Asset disposition adjustment

'

'

'

'

'

'

'

'

25

[8]

11

[8]

'

Loss from operations

'

'

'

'

'

'

'

'

182

'

'

Loss from operations after tax

'

'

'

'

'

'

'

'

109

'

'

Impairment charge

'

'

'

'

'

'

'

'

55

'

'

Impairment charge after tax

'

'

33

'

'

'

'

'

33

'

'

Loss from producer services business

'

'

'

'

'

'

'

'

127

'

'

Loss from producer services business after tax

'

'

24

'

'

'

'

'

76

'

'

Brayton Point and Kincaid

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Loss before income taxes

'

'

70

'

'

'

'

'

'

'

'

Brayton Point and Kincaid | Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Loss before income taxes

'

'

'

'

'

'

'

'

135

'

57

Income (loss) from discontinued operations

'

'

'

'

'

'

'

'

92

'

'

Amount of debt extinguishment

'

'

'

'

'

'

'

'

64

'

'

Amount of debt extinguishment after tax

'

'

'

'

'

'

'

'

38

'

'

Impairment charge

'

'

'

'

'

'

'

'

48

'

'

Long-lived assets impairment charges, net of tax

'

'

'

'

'

'

'

'

28

'

'

Loss from discontinued operation

'

'

'

'

'

'

'

'

17

'

'

Loss on discontinued operation, net of tax

'

'

'

'

'

'

'

'

18

'

'

Asset disposition adjustment

'

'

'

'

'

'

'

'

16

'

'

Loss from operations

'

'

'

'

'

'

'

'

6

'

'

Loss from operations after tax

'

'

'

'

'

'

'

'

8

'

'

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

'

'

33

Brayton Point and Kincaid | Dominion Energy

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Loss from operations after tax

'

'

57

'

'

'

'

'

'

'

'

Kewaunee | Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Loss before income taxes

'

'

'

'

'

'

'

'

'

467

'

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

'

303

'

State Line and Salem Harbor | Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Loss before income taxes

'

'

'

'

'

'

'

'

'

49

34

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

'

22

25

Virginia Electric and Power Company

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating expenses

'

'

'

'

'

'

'

'

5,215

5,234

5,641

Restoration costs net of tax

28

'

'

'

'

'

'

'

'

'

'

Asset impairment, net of tax

'

'

'

'

'

'

42

'

'

'

'

Income from operations

408

679

463

530

417

746

361

468

2,080

1,992

1,605

Virginia Electric and Power Company | Corporate and Other

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating expenses

'

'

'

'

'

'

'

'

47

51

268

Virginia Electric and Power Company | Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Charge related to Biennial Review Order

'

'

'

'

'

'

'

'

40

'

'

Restoration costs net of tax

'

'

'

'

'

'

'

'

28

'

'

Impairment charge

'

'

'

'

'

'

'

'

'

'

228

Impairment charge, net of tax

'

'

'

'

'

'

'

'

'

'

139

Impairment of emissions allowances

'

'

'

'

'

'

'

'

'

'

43

Impairment of emissions net of taxes

'

'

'

'

'

'

'

'

'

'

26

Virginia Electric and Power Company | DVP

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Charge related to Biennial Review Order

'

'

'

'

'

'

'

'

'

87

96

Restoration costs net of tax

'

'

'

'

'

'

'

'

'

$53

$59

[1]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

[2]

Includes income tax benefit of $43 million, $692 million, and $33 million in 2013, 2012 and 2011, respectively. For 2012, includes impairment charges of $1.6 billion related to Brayton Point and Kincaid. See Note 6 for additional information.

[3]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.

[4]

Segment information for 2012 and 2011 has been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.

[5]

Goodwill recorded at the Corporate and Other segment is allocated to the primary operating segments for goodwill impairment testing purposes.

[6]

Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.

[7]

See Note 3 for a discussion of Dominion's dispositions and related goodwill write-offs.

[8]

Related to assets sold or contributed to Blue Racer.

Operating_Segment_Schedule_of_

Operating Segment (Schedule of Segment Reporting Information, by Segment) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

$3,185

[1]

$3,432

$2,980

$3,523

$3,101

$3,332

$3,005

$3,397

$13,120

$12,835

[2]

$13,765

[2]

Total operating revenue

'

'

'

'

'

'

'

'

13,120

12,835

13,765

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

1,208

1,127

1,018

Equity in earnings of equity method investees

'

'

'

'

'

'

'

'

14

25

35

Interest income

'

'

'

'

'

'

'

'

54

61

67

Interest and related charges

'

'

'

'

'

'

'

'

877

816

796

Income tax expense

'

'

'

'

'

'

'

'

892

[3]

811

[2],[3]

778

[2],[3]

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

-92

-1,125

[2],[4]

-58

[2],[4]

Net income (loss) attributable to Dominion

431

[1]

569

202

495

-659

209

258

494

1,697

302

[2]

1,408

[2]

Investment in equity method affiliates

916

'

'

'

558

'

'

'

916

558

'

Capital expenditures

'

'

'

'

'

'

'

'

4,104

4,145

3,652

Total assets

50,096

'

'

'

46,838

'

'

'

50,096

46,838

'

Intersegment revenue

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

0

0

0

DVP

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

1,825

[5]

1,846

[5]

1,791

[5]

Total operating revenue

'

'

'

'

'

'

'

'

1,834

[5]

1,855

[5]

1,854

[5]

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

427

[5]

392

[5]

369

[5]

Equity in earnings of equity method investees

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Interest income

'

'

'

'

'

'

'

'

0

[5]

1

[5]

10

[5]

Interest and related charges

'

'

'

'

'

'

'

'

175

[5]

187

[5]

183

[5]

Income tax expense

'

'

'

'

'

'

'

'

287

[5]

278

[5]

264

[5]

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

475

[5]

439

[5]

416

[5]

Investment in equity method affiliates

0

[5]

'

'

'

0

[5]

'

'

'

0

[5]

0

[5]

'

Capital expenditures

'

'

'

'

'

'

'

'

1,361

[5]

1,158

[5]

1,091

[5]

Total assets

11,900

[5]

'

'

'

11,500

[5]

'

'

'

11,900

[5]

11,500

[5]

'

DVP | Intersegment revenue

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

9

[5]

9

[5]

63

[5]

Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

8,445

[5],[6]

8,170

[5],[6]

8,759

[5],[6]

Total operating revenue

'

'

'

'

'

'

'

'

8,513

[5],[6]

8,274

[5],[6]

8,882

[5],[6]

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

518

[5],[6]

483

[5],[6]

413

[5],[6]

Equity in earnings of equity method investees

'

'

'

'

'

'

'

'

-14

[5],[6]

3

[5],[6]

3

[5],[6]

Interest income

'

'

'

'

'

'

'

'

66

[5],[6]

65

[5],[6]

65

[5],[6]

Interest and related charges

'

'

'

'

'

'

'

'

220

[5],[6]

177

[5],[6]

148

[5],[6]

Income tax expense

'

'

'

'

'

'

'

'

483

[5],[6]

576

[5],[6]

655

[5],[6]

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

0

[5],[6]

0

[5],[6]

0

[5],[6]

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

1,031

[5],[6]

1,021

[5],[6]

1,078

[5],[6]

Investment in equity method affiliates

280

[5],[6]

'

'

'

414

[5],[6]

'

'

'

280

[5],[6]

414

[5],[6]

'

Capital expenditures

'

'

'

'

'

'

'

'

1,605

[5],[6]

1,615

[5],[6]

1,593

[5],[6]

Total assets

22,000

[5],[6]

'

'

'

21,800

[5],[6]

'

'

'

22,000

[5],[6]

21,800

[5],[6]

'

Dominion Generation | Intersegment revenue

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

68

[5],[6]

104

[5],[6]

123

[5],[6]

Dominion Energy

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

1,783

1,813

2,044

Total operating revenue

'

'

'

'

'

'

'

'

2,846

2,743

3,121

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

228

216

207

Equity in earnings of equity method investees

'

'

'

'

'

'

'

'

21

23

23

Interest income

'

'

'

'

'

'

'

'

12

30

27

Interest and related charges

'

'

'

'

'

'

'

'

26

47

57

Income tax expense

'

'

'

'

'

'

'

'

409

352

323

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

0

0

0

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

643

551

521

Investment in equity method affiliates

615

'

'

'

141

'

'

'

615

141

'

Capital expenditures

'

'

'

'

'

'

'

'

1,043

1,350

907

Total assets

12,100

'

'

'

11,200

'

'

'

12,100

11,200

'

Dominion Energy | Intersegment revenue

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

1,063

930

1,077

Corporate and Other

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

3

[6]

155

[6]

56

[6]

Total operating revenue

'

'

'

'

'

'

'

'

612

[6]

763

[6]

651

[6]

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

35

[6]

36

[6]

29

[6]

Equity in earnings of equity method investees

'

'

'

'

'

'

'

'

7

[6]

-1

[6]

9

[6]

Interest income

'

'

'

'

'

'

'

'

42

[6]

71

[6]

71

[6]

Interest and related charges

'

'

'

'

'

'

'

'

522

[6]

511

[6]

514

[6]

Income tax expense

'

'

'

'

'

'

'

'

-287

[6]

-395

[6]

-464

[6]

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

-92

[6]

-1,125

[6]

-58

[6]

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

-452

[6]

-1,709

[6]

-607

[6]

Investment in equity method affiliates

21

[6]

'

'

'

3

[6]

'

'

'

21

[6]

3

[6]

'

Capital expenditures

'

'

'

'

'

'

'

'

95

[6]

22

[6]

61

[6]

Total assets

8,500

[6]

'

'

'

12,600

[6]

'

'

'

8,500

[6]

12,600

[6]

'

Corporate and Other | Intersegment revenue

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

609

[6]

608

[6]

595

[6]

Adjustments & Eliminations

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

1,064

[5]

851

[5]

1,115

[5]

Total operating revenue

'

'

'

'

'

'

'

'

-685

[5]

-800

[5]

-743

[5]

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Equity in earnings of equity method investees

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Interest income

'

'

'

'

'

'

'

'

-66

[5]

-106

[5]

-106

[5]

Interest and related charges

'

'

'

'

'

'

'

'

-66

[5]

-106

[5]

-106

[5]

Income tax expense

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Loss from discontinued operations, net of tax

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Investment in equity method affiliates

0

[5]

'

'

'

0

[5]

'

'

'

0

[5]

0

[5]

'

Capital expenditures

'

'

'

'

'

'

'

'

0

[5]

0

[5]

0

[5]

Total assets

-4,400

[5]

'

'

'

-10,300

[5]

'

'

'

-4,400

[5]

-10,300

[5]

'

Adjustments & Eliminations | Intersegment revenue

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

'

'

'

'

'

'

'

'

-1,749

[5]

-1,651

[5]

-1,858

[5]

Virginia Electric and Power Company

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Operating Revenue

1,745

2,059

1,710

1,781

1,630

2,086

1,756

1,754

7,295

7,226

7,246

Total operating revenue

'

'

'

'

'

'

'

'

7,295

7,226

7,246

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

853

782

718

Interest income

'

'

'

'

'

'

'

'

6

8

18

Interest and related charges

'

'

'

'

'

'

'

'

369

385

331

Income tax expense

'

'

'

'

'

'

'

'

659

[7]

653

[7]

540

[7]

Net income (loss) attributable to Dominion

199

387

265

287

220

415

172

243

1,138

1,050

822

Capital expenditures

'

'

'

'

'

'

'

'

2,533

2,288

2,090

Total assets

26,961

'

'

'

24,811

'

'

'

26,961

24,811

'

Virginia Electric and Power Company | DVP

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenue

'

'

'

'

'

'

'

'

1,826

1,847

1,793

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

427

392

368

Interest income

'

'

'

'

'

'

'

'

0

1

10

Interest and related charges

'

'

'

'

'

'

'

'

175

186

182

Income tax expense

'

'

'

'

'

'

'

'

286

277

265

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

483

448

426

Capital expenditures

'

'

'

'

'

'

'

'

1,360

1,142

1,081

Total assets

12,000

'

'

'

11,400

'

'

'

12,000

11,400

'

Virginia Electric and Power Company | Dominion Generation

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenue

'

'

'

'

'

'

'

'

5,475

5,379

5,546

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

425

390

350

Interest income

'

'

'

'

'

'

'

'

6

7

8

Interest and related charges

'

'

'

'

'

'

'

'

192

199

199

Income tax expense

'

'

'

'

'

'

'

'

399

403

447

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

702

653

664

Capital expenditures

'

'

'

'

'

'

'

'

1,173

1,146

1,009

Total assets

15,100

'

'

'

14,800

'

'

'

15,100

14,800

'

Virginia Electric and Power Company | Corporate and Other

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenue

'

'

'

'

'

'

'

'

-6

0

-93

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

1

0

0

Interest income

'

'

'

'

'

'

'

'

0

0

0

Interest and related charges

'

'

'

'

'

'

'

'

2

0

-50

Income tax expense

'

'

'

'

'

'

'

'

-26

-27

-172

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

-47

-51

-268

Capital expenditures

'

'

'

'

'

'

'

'

0

0

0

Total assets

0

'

'

'

0

'

'

'

0

0

'

Virginia Electric and Power Company | Adjustments & Eliminations

'

'

'

'

'

'

'

'

'

'

'

Segment Reporting Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Total operating revenue

'

'

'

'

'

'

'

'

0

0

0

Depreciation, depletion and amortization

'

'

'

'

'

'

'

'

0

0

0

Interest income

'

'

'

'

'

'

'

'

0

0

0

Interest and related charges

'

'

'

'

'

'

'

'

0

0

0

Income tax expense

'

'

'

'

'

'

'

'

0

0

0

Net income (loss) attributable to Dominion

'

'

'

'

'

'

'

'

0

0

0

Capital expenditures

'

'

'

'

'

'

'

'

0

0

0

Total assets

($100)

'

'

'

($1,400)

'

'

'

($100)

($1,400)

'

[1]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.

[2]

Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.

[3]

In 2012, Dominion’s current federal income tax expense for continuing and discontinued operations includes a $195 million benefit related to a carryback of its 2012 net operating loss. In 2011, Dominion’s deferred federal income tax expense includes the recognition of a $346 million benefit, including $51 million related to discontinued operations, for its 2011 net operating loss expected to be used to reduce taxable income in future years.

[4]

Includes income tax benefit of $43 million, $692 million, and $33 million in 2013, 2012 and 2011, respectively. For 2012, includes impairment charges of $1.6 billion related to Brayton Point and Kincaid. See Note 6 for additional information.

[5]

Amounts have been recast to reflect nonregulated retail energy marketing operations in the Dominion Generation segment.

[6]

Segment information for 2012 and 2011 has been recast to reflect Brayton Point and Kincaid as discontinued operations, as discussed in Note 3.

[7]

In 2011, Virginia Power’s deferred federal income tax expense includes a $54 million benefit related to a portion of its 2011 net operating loss that is expected to be used in future years. Also, Virginia Power’s current federal income tax expense reflects the amounts of its 2011 net operating losses realized through its participation in a tax sharing agreement with Dominion and its subsidiaries.

Quarterly_Financial_and_Common2

Quarterly Financial and Common Stock Data (Unaudited) (Narrative) (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Jun. 30, 2013

Sep. 30, 2012

Dec. 31, 2013

Jun. 30, 2012

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Brayton Point and Kincaid

Kewaunee

Virginia Electric and Power Company

Virginia Electric and Power Company

Dominion Energy

Dominion Energy

Dominion Energy

Dominion Generation

Dominion Generation

Dominion Generation

Dominion Generation

Dominion Generation

Brayton Point Kincaid And Elwood Power Stations

Brayton Point Kincaid And Elwood Power Stations

Brayton Point and Kincaid

Brayton Point and Kincaid

Brayton Point and Kincaid

Kewaunee

Virginia Electric and Power Company

Dominion Generation

Dominion Generation

Condensed Financial Statements, Captions [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Loss before income taxes

'

($70)

'

'

'

'

'

'

'

($135)

($57)

($467)

'

'

($1,700)

Loss from operations after tax

'

'

'

'

'

'

109

57

'

8

'

'

'

'

'

Impairment charge after tax

'

'

'

'

'

33

33

'

'

'

'

'

'

'

'

Loss from producer services business after tax

'

'

'

'

'

24

76

'

'

'

'

'

'

'

'

Impairment charge

1,600

'

'

'

'

'

'

'

'

48

'

'

'

1,000

'

Impairment and other charges

'

'

281

'

'

'

'

'

'

'

'

'

'

'

'

Restoration costs net of tax

'

'

'

28

'

'

'

'

'

'

'

'

28

'

'

Asset impairment, net of tax

'

'

'

'

$42

'

'

'

$139

'

'

'

'

'

'

Quarterly_Financial_and_Common3

Quarterly Financial and Common Stock Data (Unaudited) (Quarterly Financial and Common Stock Data) (Details) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2012		Sep. 30, 2012		Jun. 30, 2012		Mar. 31, 2012		Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Condensed Financial Statements, Captions [Line Items]	'		'		'		'		'		'		'		'		'		'		'
Operating Revenue	$3,185	[1]	$3,432		$2,980		$3,523		$3,101		$3,332		$3,005		$3,397		$13,120		$12,835	[2]	$13,765	[2]
Income from operations	804	[1]	1,034		548		930		761		551		628		918		3,316		2,858	[2]	2,880	[2]
Net income including noncontrolling interests	435	[1]	575		208		502		-652		215		265		501		1,720		329	[2]	1,426	[2]
Income from continuing operations	431	[1],[3]	592	[3]	272	[3]	494	[3]	372	[3]	261	[3]	290	[3]	504	[3]	1,789	[3]	1,427	[2],[3]	1,466	[2]
Income (loss) from discontinued operations	0	[1],[3]	-23	[3]	-70	[3]	1	[3]	-1,031	[3]	-52	[3]	-32	[3]	-10	[3]	-92	[3]	-1,125	[3]	'
Net income (loss) attributable to Dominion	431	[1]	569		202		495		-659		209		258		494		1,697		302	[2]	1,408	[2]
Income from continuing operations - basic (in dollars per share)	$0.74	[1],[3]	$1.02	[3]	$0.47	[3]	$0.86	[3]	$0.65	[3]	$0.45	[3]	$0.51	[3]	$0.88	[3]	$3.09	[3]	$2.49	[2],[3]	$2.56	[2]
Income (loss) from discontinued operations - basic (in dollars per share)	$0	[1],[3]	($0.04)	[3]	($0.12)	[3]	$0	[3]	($1.80)	[3]	($0.09)	[3]	($0.06)	[3]	($0.02)	[3]	($0.16)	[3]	($1.96)	[2],[3]	($0.10)	[2]
Net income attributable to Dominion (in dollars per share)	$0.74	[1]	$0.98		$0.35		$0.86		($1.15)		$0.36		$0.45		$0.86		$2.93		$0.53	[2]	$2.46	[2]
Income from continuing operations - diluted (in dollars per share)	$0.74	[1],[3]	$1.02	[3]	$0.47	[3]	$0.86	[3]	$0.64	[3]	$0.45	[3]	$0.51	[3]	$0.88	[3]	$3.09	[3]	$2.49	[2],[3]	$2.55	[2]
Income (loss) from discontinued operations - diluted (in dollars per share)	$0	[1],[3]	($0.04)	[3]	($0.12)	[3]	$0	[3]	($1.79)	[3]	($0.09)	[3]	($0.06)	[3]	($0.02)	[3]	($0.16)	[3]	($1.96)	[2],[3]	($0.10)	[2]
Net income attributable to Dominion - diluted (in dollars per share)	$0.74	[1]	$0.98		$0.35		$0.86		($1.15)		$0.36		$0.45		$0.86		$2.93		$0.53	[2]	$2.45	[2]
Dividends declared per common share	$0.56	[1]	$0.56		$0.56		$0.56		$0.53		$0.53		$0.53		$0.53		$2.25		$2.11	[2]	$1.97	[2]
Virginia Electric and Power Company	'		'		'		'		'		'		'		'		'		'		'
Condensed Financial Statements, Captions [Line Items]	'		'		'		'		'		'		'		'		'		'		'
Operating Revenue	1,745		2,059		1,710		1,781		1,630		2,086		1,756		1,754		7,295		7,226		7,246
Income from operations	408		679		463		530		417		746		361		468		2,080		1,992		1,605
Net income (loss) attributable to Dominion	199		387		265		287		220		415		172		243		1,138		1,050		822
Balance available for common stock	$194		$383		$261		$283		$216		$411		$168		$239		$1,121		$1,034		$805
Maximum	'		'		'		'		'		'		'		'		'		'		'
Condensed Financial Statements, Captions [Line Items]	'		'		'		'		'		'		'		'		'		'		'
Share Price	$67.97		$64.04		$61.85		$58.25		$53.89		$55.62		$54.69		$53.68		$67.97		$53.89		'
Common stock market value (high)	'		'		'		'		'		'		'		'		$67.97		$55.62		'
Minimum	'		'		'		'		'		'		'		'		'		'		'
Condensed Financial Statements, Captions [Line Items]	'		'		'		'		'		'		'		'		'		'		'
Share Price	$61.36		$55.51		$53.79		$51.92		$48.94		$52.15		$49.87		$48.87		$61.36		$48.94		'
Common stock market value (low)	'		'		'		'		'		'		'		'		$51.92		$48.87		'
[1]	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3.
[2]	Recast to reflect Brayton Point and Kincaid as discontinued operations as described in Note 3 to the Consolidated Financial Statements. EPS amounts reflect the per share impact of the recast of $1.92 and $0.06 for 2012 and 2011, respectively.
[3]	Amounts attributable to Dominion's common shareholders.