Duke Energy Progress 10-Q8 Nov 132013 Q3 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
Document and Entity Information	Sep. 30, 2013	Nov. 05, 2013
Document Information [Line Items]	'	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Amendment Flag	'false	'
Entity Registrant Name	'Duke Energy Corporation	'
Entity Central Index Key	'0001326160	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	705,993,361
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Duke Energy Carolinas [Member]	'	'
Document Information [Line Items]	'	'
Entity Registrant Name	'Duke Energy Carolinas, LLC	'
Entity Central Index Key	'0000030371	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Progress Energy [Member]	'	'
Document Information [Line Items]	'	'
Entity Registrant Name	'Progress Energy, Inc	'
Entity Central Index Key	'0001094093	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Duke Energy Progress [Member]	'	'
Document Information [Line Items]	'	'
Entity Registrant Name	'Duke Energy Progress, Inc.	'
Entity Central Index Key	'0000017797	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Duke Energy Florida [Member]	'	'
Document Information [Line Items]	'	'
Entity Registrant Name	'Duke Energy Florida, Inc.	'
Entity Central Index Key	'0000037637	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Duke Energy Ohio [Member]	'	'
Document Information [Line Items]	'	'
Entity Registrant Name	'Duke Energy Ohio, Inc.	'
Entity Central Index Key	'0000020290	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Duke Energy Indiana [Member]	'	'
Document Information [Line Items]	'	'
Entity Registrant Name	'Duke Energy Indiana, Inc.	'
Entity Central Index Key	'0000081020	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (Unaudited) (USD $)	3 Months Ended				9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Operating Revenues [Abstract]	'		'		'		'
Regulated electric	$5,718		$5,763		$15,441		$10,892
Non-regulated electric, natural gas, and other	908		882		2,683		2,708
Regulated natural gas	83		77		362		329
Total operating revenues	6,709		6,722		18,486		13,929
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	2,013		2,222		5,394		3,848
Fuel used in electric generation and purchased power - non-regulated	428		484		1,329		1,328
Cost of natural gas and coal sold	33		40		180		184
Operation, maintenance and other	1,458		1,654		4,383		3,262
Depreciation and amortization	707		666		2,045		1,620
Property and other taxes	325		326		991		681
Impairment charges	2		266		388		668
Total operating expenses	4,966		5,658		14,710		11,591
Gains (Losses) on Sales of Other Assets and Other, net	0		14		3		21
Operating Income (Loss)	1,743		1,078		3,779		2,359
Other Income and Expenses [Abstract]	'		'		'		'
Equity in earnings of unconsolidated affiliates	33		33		91		118
Other income and expenses, net	54		132		182		285
Total other income and expenses	87		165		273		403
Interest Expense	379		401		1,127		857
Income (Loss) From Continuing Operations Before Income Taxes	1,451		842		2,925		1,905
Income Tax Expense or Benefit from Continuing Operations	457		248		952		565
Income (Loss) from Continuing Operations	994		594		1,973		1,340
Income (Loss) From Discontinued Operations, net of tax	14		4		11		5
Net Income (Loss)	1,008		598		1,984		1,345
Less: Net Income (Loss) Attributable to Noncontrolling Interests	4		4		7		12
Net Income (Loss) Attributable to Duke Energy	1,004		594		1,977		1,333
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Pension and OPEB related adjustments	'		-21	[1]	5	[1]	-15	[1]
Net unrealized gain (loss) on cash flow hedges	1	[2]	-2	[2]	55	[2]	-19	[2]
Reclassification into earnings from cash flow hedges	-1		2		-1		'
Other Comprehensive Income Unrealized Holding Gain Loss On Auction Rate Securities Arising During Period Net Of Tax	'		1		'		7
Other comprehensive income (loss), net of tax	-4		-20		-78		-110
Comprehensive Income (Loss)	1,004		578		1,906		1,235
Less: Comprehensive Income Attributable to Noncontrolling Interests	4		4		3		8
Comprehensive income (loss)	1,000		574		1,903		1,227
Income From Continuing Operations Attributable To Parent Common Shareholders [Abstract]	'		'		'		'
Basic	$1.40		$0.84		$2.78		$2.50
Diluted	$1.40		$0.84		$2.78		$2.50
Income (loss) from discontinued operations attributable To Duke Energy Corporation common shareholders [Abstract]	'		'		'		'
Basic	$0.02		$0.01		$0.01		$0.01
Diluted	$0.02		$0.01		$0.01		$0.01
Net income attributable to Duke Energy Corporation common shareholders [Abstract]	'		'		'		'
Basic	$1.42		$0.85		$2.79		$2.51
Diluted	$1.42		$0.85		$2.79		$2.51
Dividends declared per share	$0		$0		$2.31		$2.27
Weighted-average shares outstanding [Abstract]	'		'		'		'
Basic	706		699		706		531
Diluted	706		699		706		531
Duke Energy Carolinas [Member]	'		'		'		'
Operating Revenues [Abstract]	'		'		'		'
Total operating revenues	1,919		1,939		5,239		5,056
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	539		576		1,500		1,398
Operation, maintenance and other	456		562		1,392		1,369
Depreciation and amortization	228		233		676		687
Property and other taxes	90		100		282		279
Impairment charges	'		31		'		31
Total operating expenses	1,313		1,502		3,850		3,764
Gains (Losses) on Sales of Other Assets and Other, net	-2		3		0		9
Operating Income (Loss)	604		440		1,389		1,301
Other Income and Expenses [Abstract]	'		'		'		'
Total other income and expenses	29		48		94		130
Interest Expense	82		95		255		285
Income (Loss) From Continuing Operations Before Income Taxes	551		393		1,228		1,146
Income Tax Expense or Benefit from Continuing Operations	209		135		461		411
Net Income (Loss)	342		258		767		735
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Reclassification into earnings from cash flow hedges	1		0		1		2
Other comprehensive income (loss), net of tax	'		'		1		2
Comprehensive Income (Loss)	343		258		768		737
Progress Energy [Member]	'		'		'		'
Operating Revenues [Abstract]	'		'		'		'
Total operating revenues	2,766		2,788		7,233		7,178
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	1,154		1,396		2,932		3,299
Operation, maintenance and other	559		626		1,653		1,798
Depreciation and amortization	240		174		644		571
Property and other taxes	141		160		423		440
Impairment charges	2		55		368		55
Total operating expenses	2,096		2,411		6,020		6,163
Gains (Losses) on Sales of Other Assets and Other, net	1		2		2		4
Operating Income (Loss)	671		379		1,215		1,019
Other Income and Expenses [Abstract]	'		'		'		'
Total other income and expenses	26		32		63		97
Interest Expense	162		182		520		560
Income (Loss) From Continuing Operations Before Income Taxes	535		229		758		556
Income Tax Expense or Benefit from Continuing Operations	207		75		289		193
Income (Loss) from Continuing Operations	328		154		469		363
Income (Loss) From Discontinued Operations, net of tax	14		3		10		10
Net Income (Loss)	342		157		479		373
Less: Net Income (Loss) Attributable to Noncontrolling Interests	1		2		2		5
Net Income (Loss) Attributable to Duke Energy	341		155		477		368
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Pension and OPEB related adjustments	4		1		5		0
Net unrealized gain (loss) on cash flow hedges	-3		0		0		-5
Reclassification into earnings from cash flow hedges	3		0		3		7
Reclassification of cash flow hedges to regulatory assets	0		97	[3]	0		97	[3]
Other comprehensive income (loss), net of tax	4		98		8		99
Comprehensive income (loss)	346		255		487		472
Duke Energy Progress [Member]	'		'		'		'
Operating Revenues [Abstract]	'		'		'		'
Total operating revenues	1,430		1,398		3,781		3,578
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	574		597		1,470		1,450
Operation, maintenance and other	352		384		1,044		1,146
Depreciation and amortization	143		131		393		399
Property and other taxes	59		60		172		168
Impairment charges	0		55		22		55
Total operating expenses	1,128		1,227		3,101		3,218
Gains (Losses) on Sales of Other Assets and Other, net	1		1		1		2
Operating Income (Loss)	303		172		681		362
Other Income and Expenses [Abstract]	'		'		'		'
Total other income and expenses	21		21		43		57
Interest Expense	52		52		147		156
Income (Loss) From Continuing Operations Before Income Taxes	272		141		577		263
Income Tax Expense or Benefit from Continuing Operations	97		45		215		83
Net Income (Loss)	175		96		362		180
Less: Preferred Stock Dividend Requirement	0		1		0		2
Net Income (Loss) Available to Parent	175		95		362		178
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Net unrealized gain (loss) on cash flow hedges	0		1		0		-4
Reclassification into earnings from cash flow hedges	0		0		0		4
Reclassification of cash flow hedges to regulatory assets	0		71	[4]	0		71	[4]
Other comprehensive income (loss), net of tax	0		72		0		71
Comprehensive income (loss)	175		168		362		251
Duke Energy Florida [Member]	'		'		'		'
Operating Revenues [Abstract]	'		'		'		'
Total operating revenues	1,332		1,388		3,442		3,594
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	579		799		1,462		1,849
Operation, maintenance and other	207		245		616		660
Depreciation and amortization	95		39		237		158
Property and other taxes	81		99		245		271
Impairment charges	1		0		346		0
Total operating expenses	963		1,182		2,906		2,938
Gains (Losses) on Sales of Other Assets and Other, net	0		1		1		2
Operating Income (Loss)	369		207		537		658
Other Income and Expenses [Abstract]	'		'		'		'
Total other income and expenses	6		11		19		29
Interest Expense	46		62		138		194
Income (Loss) From Continuing Operations Before Income Taxes	329		156		418		493
Income Tax Expense or Benefit from Continuing Operations	132		56		168		182
Net Income (Loss)	197		100		250		311
Less: Preferred Stock Dividend Requirement	0		0		0		1
Net Income (Loss) Available to Parent	197		100		250		310
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Pension and OPEB related adjustments	-1		0		-1		0
Reclassification of cash flow hedges to regulatory assets	0		26		0		26
Other comprehensive income (loss), net of tax	-1		26		-1		26
Comprehensive income (loss)	196		126		249		337
Duke Energy Ohio [Member]	'		'		'		'
Operating Revenues [Abstract]	'		'		'		'
Regulated electric	371		387		1,043		1,047
Non-regulated electric, natural gas, and other	364		292		970		1,008
Regulated natural gas	84		78		364		331
Total operating revenues	819		757		2,377		2,386
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	121		141		327		375
Fuel used in electric generation and purchased power - non-regulated	234		234		696		649
Cost of natural gas and coal sold	9		8		102		95
Operation, maintenance and other	187		208		584		579
Depreciation and amortization	88		86		265		249
Property and other taxes	65		38		201		166
Total operating expenses	704		715		2,175		2,113
Gains (Losses) on Sales of Other Assets and Other, net	1		0		5		2
Operating Income (Loss)	116		42		207		275
Other Income and Expenses [Abstract]	'		'		'		'
Total other income and expenses	1		5		4		13
Interest Expense	14		21		50		70
Income (Loss) From Continuing Operations Before Income Taxes	103		26		161		218
Income Tax Expense or Benefit from Continuing Operations	44		12		65		85
Net Income (Loss)	59		14		96		133
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Pension and OPEB related adjustments	0		0		1		1
Other comprehensive income (loss), net of tax	'		'		1		1
Comprehensive income (loss)	59		14		97		134
Duke Energy Indiana [Member]	'		'		'		'
Operating Revenues [Abstract]	'		'		'		'
Total operating revenues	755		718		2,179		2,091
Operating Expenses [Abstract]	'		'		'		'
Fuel used in electric generation and purchased power - regulated	283		283		852		853
Operation, maintenance and other	176		162		489		473
Depreciation and amortization	72		100		227		292
Property and other taxes	21		23		59		61
Impairment charges	0		180		0		580
Total operating expenses	552		748		1,627		2,259
Operating Income (Loss)	203		-30		552		-168
Other Income and Expenses [Abstract]	'		'		'		'
Total other income and expenses	4		24		14		66
Interest Expense	43		35		127		105
Income (Loss) From Continuing Operations Before Income Taxes	164		-41		439		-207
Income Tax Expense or Benefit from Continuing Operations	60		-22		163		-98
Net Income (Loss)	104		-19		276		-109
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Reclassification into earnings from cash flow hedges	-1		0		-2		-1
Other comprehensive income (loss), net of tax	'		'		-2		-1
Comprehensive income (loss)	$103		($19)		$274		($110)

[1]	Net of insignificant tax expense and $2 million tax expense for the three and nine months ended September 30, 2013 and $10 million tax benefit and $7 million tax benefit for the three and nine months ended September 30, 2012.
[2]	Net of $1 million tax benefit and $17 million tax expense for the three and nine months ended September 30, 2013 and $1 million tax benefit and $10 million tax benefit for the three and nine months ended September 30, 2012.
[3]	Net of tax expense of $62 million in 2012.
[4]	Net of $46 million tax expense in 2012.

Condensed_Consolidated_Stateme1

Condensed Consolidated Statement of Operations (Unaudited) (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension and OPEB related adjustments to AOCI, tax	'	$10	($2)	$7
Net unrealized gains (losses) on cash flow hedges, tax	-1	-1	17	-10
Progress Energy [Member]	'	'	'	'
Reclassification of cash flow hedges to regulatory assets, tax	0	62	0	62
Duke Energy Progress [Member]	'	'	'	'
Reclassification of cash flow hedges to regulatory assets, tax	0	46	0	46
Duke Energy Florida [Member]	'	'	'	'
Reclassification of cash flow hedges to regulatory assets, tax	$0	$17	$0	$17

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Statement of Comprehensive Income [Abstract]	'		'		'		'
Net Income	$1,008		$598		$1,984		$1,345
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'		'		'		'
Foreign currency translation adjustments	-8		2		-137		-85
Pension and OPEB related adjustments	'		-21	[1]	5	[1]	-15	[1]
Net unrealized gain (loss) on cash flow hedges	1	[2]	-2	[2]	55	[2]	-19	[2]
Reclassification into earnings from cash flow hedges	1		-2		1		'
Unrealized gain (loss) on investments in auction rate securities	'		1		'		7
Unrealized gain (loss) on investments in available for sale securities	-1		3		-5		6
Reclassification into earnings from available for sale securities	3		-1		3		-4
Other Comprehensive Income (Loss), Net of Tax	-4		-20		-78		-110
Comprehensive Income	1,004		578		1,906		1,235
Less: Comprehensive Income Attributable to Noncontrolling Interests	4		4		3		8
Comprehensive Income Attributable to Duke Energy Corporation	$1,000		$574		$1,903		$1,227

[1]	Net of insignificant tax expense and $2 million tax expense for the three and nine months ended September 30, 2013 and $10 million tax benefit and $7 million tax benefit for the three and nine months ended September 30, 2012.
[2]	Net of $1 million tax benefit and $17 million tax expense for the three and nine months ended September 30, 2013 and $1 million tax benefit and $10 million tax benefit for the three and nine months ended September 30, 2012.

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthethical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension and OPEB related adjustments to AOCI, tax	'	$10	($2)	$7
Net unrealized gains (losses) on cash flow hedges, tax	($1)	($1)	$17	($10)

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (Unaudited) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current Assets [Abstract]	'	'
Cash and cash equivalents	$2,166	$1,424
Short Term Investments	118	333
Receivables (net of allowance for doubtful accounts)	1,585	1,516
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	1,258	1,201
Inventory	3,100	3,223
Other	2,191	2,425
Total current assets	10,418	10,122
Investments and Other Assets [Abstract]	'	'
Investments in equity method unconsolidated affiliates	511	483
Nuclear decommissioning trust funds	4,805	4,242
Goodwill	16,345	16,365
Intangibles, net	351	372
Notes receivable	65	71
Restricted other assets of variable interest entities	52	62
Other	2,361	2,399
Total investments and other assets	24,490	23,994
Property, Plant and Equipment [Abstract]	'	'
Cost	100,682	98,833
Cost, variable interest entities	1,679	1,558
Accumulated depreciation and amortization	-33,136	-31,969
Generation facilities to be retired, net	59	136
Net property, plant and equipment	69,284	68,558
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	10,220	11,004
Other	178	178
Total regulatory assets and deferred debits	10,398	11,182
Total Assets	114,590	113,856
Current Liabilities [Abstract]	'	'
Accounts payable	1,819	2,444
Notes payable and commercial paper	1,278	745
Non-recourse notes payable of variable interest entities	325	312
Taxes accrued	706	459
Interest accrued	474	448
Current maturities of long-term debt	2,307	3,110
Other	2,330	2,511
Total current liabilities	9,239	10,029
Long-term Debt	36,137	35,499
Non-recourse long-term debt of variable interest entities	1,265	852
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	11,489	10,490
Investment tax credits	446	458
Accrued pension and other post-retirement benefit costs	1,743	2,520
Asset retirement obligations	5,341	5,169
Regulatory liabilities	5,904	5,584
Other	1,789	2,221
Total deferred credits and other liabilities	26,712	26,442
Commitments and Contingencies	'	'
Preferred Stock of Subsidiaries	0	93
Equity [Abstract]	'	'
Common stock	1	1
Additional paid-in capital	39,317	39,279
Retained earnings	2,227	1,889
Accumulated other comprehensive (loss) income	-380	-306
Total Common Shareholders' Equity	41,165	40,863
Noncontrolling interests	72	78
Total equity	41,237	40,941
Total Liabilities and Equity	114,590	113,856
Duke Energy Carolinas [Member]	'	'
Current Assets [Abstract]	'	'
Cash and cash equivalents	25	19
Receivables (net of allowance for doubtful accounts)	140	188
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	703	637
Receivables from affiliated companies	40	3
Notes receivable from affiliated companies	595	382
Inventory	1,033	1,062
Other	474	439
Total current assets	3,010	2,730
Investments and Other Assets [Abstract]	'	'
Nuclear decommissioning trust funds	2,673	2,354
Other	845	934
Total investments and other assets	3,518	3,288
Property, Plant and Equipment [Abstract]	'	'
Cost	34,916	34,190
Accumulated depreciation and amortization	-11,731	-11,437
Generation facilities to be retired, net	0	73
Net property, plant and equipment	23,185	22,826
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	1,794	1,727
Other	45	71
Total regulatory assets and deferred debits	1,839	1,798
Total Assets	31,552	30,642
Current Liabilities [Abstract]	'	'
Accounts payable	451	599
Accounts payable to affiliated companies	235	128
Taxes accrued	156	114
Interest accrued	142	96
Current maturities of long-term debt	447	406
Other	461	490
Total current liabilities	1,892	1,833
Long-term Debt	7,692	7,735
Non-recourse long-term debt of variable interest entities	300	300
Long-term debt payable to affiliated companies	300	300
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	5,537	5,181
Investment tax credits	211	215
Accrued pension and other post-retirement benefit costs	211	221
Asset retirement obligations	2,053	1,959
Regulatory liabilities	2,484	2,102
Other	732	924
Total deferred credits and other liabilities	11,228	10,602
Commitments and Contingencies	'	'
Equity [Abstract]	'	'
Member's equity	10,155	9,888
Accumulated other comprehensive (loss) income	-15	-16
Total Member's Equity	10,140	9,872
Total Liabilities and Member's Equity	31,552	30,642
Progress Energy [Member]	'	'
Current Assets [Abstract]	'	'
Cash and cash equivalents	66	231
Receivables (net of allowance for doubtful accounts)	1,020	790
Receivables from affiliated companies	3	15
Notes receivable from affiliated companies	103	0
Inventory	1,361	1,441
Other	761	766
Total current assets	3,314	3,243
Investments and Other Assets [Abstract]	'	'
Nuclear decommissioning trust funds	2,132	1,888
Goodwill	3,655	3,655
Other	531	530
Total investments and other assets	6,318	6,073
Property, Plant and Equipment [Abstract]	'	'
Cost	35,922	35,130
Cost, variable interest entities	16	16
Accumulated depreciation and amortization	-12,916	-12,512
Generation facilities to be retired, net	59	63
Net property, plant and equipment	23,081	22,697
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	4,620	5,292
Other	97	100
Total regulatory assets and deferred debits	4,717	5,392
Total Assets	37,430	37,405
Current Liabilities [Abstract]	'	'
Accounts payable	770	1,066
Accounts payable to affiliated companies	55	30
Notes payable to affiliated companies	1,195	455
Taxes accrued	246	83
Interest accrued	192	192
Current maturities of long-term debt	317	843
Other	1,177	1,118
Total current liabilities	3,952	3,787
Long-term Debt	13,498	13,311
Long-term debt payable to affiliated companies	0	274
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	2,962	2,558
Investment tax credits	89	95
Accrued pension and other post-retirement benefit costs	994	1,608
Asset retirement obligations	2,486	2,413
Regulatory liabilities	2,385	2,469
Other	397	612
Total deferred credits and other liabilities	9,313	9,755
Commitments and Contingencies	'	'
Preferred Stock of Subsidiaries	0	93
Equity [Abstract]	'	'
Common stock	0	0
Additional paid-in capital	7,465	7,465
Retained earnings	3,257	2,783
Accumulated other comprehensive (loss) income	-59	-67
Total Common Shareholders' Equity	10,663	10,181
Noncontrolling interests	4	4
Total equity	10,667	10,185
Total Liabilities and Equity	37,430	37,405
Duke Energy Progress [Member]	'	'
Current Assets [Abstract]	'	'
Cash and cash equivalents	32	18
Receivables (net of allowance for doubtful accounts)	553	458
Receivables from affiliated companies	1	5
Inventory	795	828
Other	407	313
Total current assets	1,788	1,622
Investments and Other Assets [Abstract]	'	'
Nuclear decommissioning trust funds	1,425	1,259
Other	297	251
Total investments and other assets	1,722	1,510
Property, Plant and Equipment [Abstract]	'	'
Cost	21,876	21,168
Cost, variable interest entities	16	16
Accumulated depreciation and amortization	-8,509	-8,185
Generation facilities to be retired, net	59	63
Net property, plant and equipment	13,442	13,062
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	1,558	1,845
Other	32	29
Total regulatory assets and deferred debits	1,590	1,874
Total Assets	18,542	18,068
Current Liabilities [Abstract]	'	'
Accounts payable	399	542
Accounts payable to affiliated companies	76	76
Notes payable to affiliated companies	581	364
Taxes accrued	86	23
Interest accrued	74	69
Current maturities of long-term debt	7	407
Other	440	517
Total current liabilities	1,663	1,998
Long-term Debt	4,929	4,433
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	2,435	2,162
Investment tax credits	87	92
Accrued pension and other post-retirement benefit costs	325	715
Asset retirement obligations	1,709	1,649
Regulatory liabilities	1,743	1,538
Other	164	295
Total deferred credits and other liabilities	6,463	6,451
Commitments and Contingencies	'	'
Preferred stock	0	59
Equity [Abstract]	'	'
Common stock	2,159	2,159
Retained earnings	3,328	2,968
Total equity	5,487	5,127
Total Liabilities and Equity	18,542	18,068
Duke Energy Florida [Member]	'	'
Current Assets [Abstract]	'	'
Cash and cash equivalents	15	131
Receivables (net of allowance for doubtful accounts)	458	318
Receivables from affiliated companies	1	20
Notes receivable from affiliated companies	30	207
Inventory	567	613
Other	325	351
Total current assets	1,396	1,640
Investments and Other Assets [Abstract]	'	'
Nuclear decommissioning trust funds	707	629
Other	176	182
Total investments and other assets	883	811
Property, Plant and Equipment [Abstract]	'	'
Cost	13,702	13,432
Accumulated depreciation and amortization	-4,188	-4,072
Net property, plant and equipment	9,514	9,360
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	3,007	3,321
Other	45	48
Total regulatory assets and deferred debits	3,052	3,369
Total Assets	14,845	15,180
Current Liabilities [Abstract]	'	'
Accounts payable	336	412
Accounts payable to affiliated companies	25	44
Taxes accrued	200	48
Interest accrued	65	55
Current maturities of long-term debt	11	435
Other	667	534
Total current liabilities	1,304	1,528
Long-term Debt	4,876	4,885
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	1,782	1,518
Accrued pension and other post-retirement benefit costs	475	610
Asset retirement obligations	777	764
Regulatory liabilities	640	787
Other	169	255
Total deferred credits and other liabilities	3,843	3,934
Commitments and Contingencies	'	'
Preferred stock	0	34
Equity [Abstract]	'	'
Common stock	1,762	1,762
Retained earnings	3,061	3,037
Accumulated other comprehensive (loss) income	-1	0
Total equity	4,822	4,799
Total Liabilities and Equity	14,845	15,180
Duke Energy Ohio [Member]	'	'
Current Assets [Abstract]	'	'
Cash and cash equivalents	27	31
Receivables (net of allowance for doubtful accounts)	114	108
Receivables from affiliated companies	81	82
Notes receivable from affiliated companies	46	1
Inventory	198	227
Other	292	267
Total current assets	758	716
Investments and Other Assets [Abstract]	'	'
Goodwill	920	921
Intangibles, net	120	129
Other	98	75
Total investments and other assets	1,138	1,125
Property, Plant and Equipment [Abstract]	'	'
Cost	11,050	10,824
Accumulated depreciation and amortization	-2,859	-2,698
Net property, plant and equipment	8,191	8,126
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	556	579
Other	14	14
Total regulatory assets and deferred debits	570	593
Total Assets	10,657	10,560
Current Liabilities [Abstract]	'	'
Accounts payable	248	318
Accounts payable to affiliated companies	66	62
Notes payable to affiliated companies	69	245
Taxes accrued	136	159
Interest accrued	28	14
Current maturities of long-term debt	5	261
Other	114	126
Total current liabilities	666	1,185
Long-term Debt	2,183	1,736
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	1,969	1,853
Investment tax credits	6	6
Accrued pension and other post-retirement benefit costs	144	157
Asset retirement obligations	30	28
Regulatory liabilities	257	254
Other	139	175
Total deferred credits and other liabilities	2,545	2,473
Commitments and Contingencies	'	'
Equity [Abstract]	'	'
Common stock	762	762
Additional paid-in capital	4,882	4,882
Retained earnings	-381	-477
Accumulated other comprehensive (loss) income	0	-1
Total equity	5,263	5,166
Total Liabilities and Equity	10,657	10,560
Duke Energy Indiana [Member]	'	'
Current Assets [Abstract]	'	'
Cash and cash equivalents	25	36
Receivables (net of allowance for doubtful accounts)	11	33
Receivables from affiliated companies	123	104
Notes receivable from affiliated companies	69	0
Inventory	413	380
Other	216	138
Total current assets	857	691
Investments and Other Assets [Abstract]	'	'
Intangibles, net	33	41
Other	160	122
Total investments and other assets	193	163
Property, Plant and Equipment [Abstract]	'	'
Cost	12,310	12,012
Accumulated depreciation and amortization	-3,839	-3,692
Net property, plant and equipment	8,471	8,320
Regulatory Assets and Deferred Debits [Abstract]	'	'
Regulatory assets	790	810
Other	25	24
Total regulatory assets and deferred debits	815	834
Total Assets	10,336	10,008
Current Liabilities [Abstract]	'	'
Accounts payable	114	173
Accounts payable to affiliated companies	53	60
Notes payable to affiliated companies	0	81
Taxes accrued	66	61
Interest accrued	53	53
Current maturities of long-term debt	4	405
Other	101	165
Total current liabilities	391	998
Long-term Debt	3,644	3,147
Long-term debt payable to affiliated companies	150	150
Deferred Credits and Other Liabilities [Abstract]	'	'
Deferred income taxes	1,126	853
Investment tax credits	141	142
Accrued pension and other post-retirement benefit costs	182	186
Asset retirement obligations	37	37
Regulatory liabilities	766	741
Other	42	46
Total deferred credits and other liabilities	2,294	2,005
Commitments and Contingencies	'	'
Equity [Abstract]	'	'
Common stock	1	1
Additional paid-in capital	1,384	1,384
Retained earnings	2,469	2,318
Accumulated other comprehensive (loss) income	3	5
Total equity	3,857	3,708
Total Liabilities and Equity	$10,336	$10,008

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Receivables, allowance for doubtful accounts	$31	$34
Restricted receivables, allowance for doubtful accounts	42	44
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	2,000,000,000	2,000,000,000
Common stock, shares outstanding	706,000,000	704,000,000
Duke Energy Carolinas [Member]	'	'
Receivables, allowance for doubtful accounts	3	3
Restricted receivables, allowance for doubtful accounts	6	6
Progress Energy [Member]	'	'
Receivables, allowance for doubtful accounts	14	16
Common stock, par value	$0.01	$0.01
Common stock, shares authorized	100	100
Common stock, shares outstanding	100	100
Duke Energy Progress [Member]	'	'
Receivables, allowance for doubtful accounts	9	9
Common stock, shares authorized	200,000,000	200,000,000
Common stock, shares outstanding	160,000,000	160,000,000
Duke Energy Florida [Member]	'	'
Receivables, allowance for doubtful accounts	4	7
Common stock, shares authorized	60,000,000	60,000,000
Common stock, shares outstanding	100	100
Duke Energy Ohio [Member]	'	'
Receivables, allowance for doubtful accounts	2	2
Common stock, par value	$8.50	$8.50
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares outstanding	89,663,086	89,663,086
Duke Energy Indiana [Member]	'	'
Receivables, allowance for doubtful accounts	$1	$1
Common stock, par value	$0.01	$0.01
Common stock, shares authorized	60,000,000	60,000,000
Common stock, shares outstanding	53,913,701	53,913,701

Condensed_Consolidated_Stateme4

Condensed Consolidated Statements of Cash Flows (Unaudited) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	$1,984	$1,345
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	2,365	1,865
Equity component of AFUDC	-121	-209
Severance expense	0	73
FERC mitigation costs	0	117
Community support and charitable contributions expense	34	100
(Gains) losses on sales of other assets	8	-21
Impairment of other long-lived assets	388	588
Deferred income taxes	1,014	437
Equity in earnings of unconsolidated affiliates	-91	-118
Voluntary opportunity cost deferral	0	-101
Accrued pension and other post-retirement benefit costs	259	152
Contributions to qualified pension plans	-27	-79
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	-14	68
Receivables	-154	-83
Inventory	119	-22
Other current assets	-48	101
Increase (decrease) in [Abstract]	'	'
Accounts payable	-412	-222
Taxes accrued	245	-7
Other current liabilities	-31	128
Other assets	-307	-167
Other liabilities	-221	34
Net cash provided by (used in) operating activities	4,990	3,979
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-3,854	-3,845
Investment expenditures	-53	-7
Acquisitions	0	-36
Cash acquired from acquisition	0	71
Purchases of available-for-sale securities	-4,591	-2,159
Proceeds from sales and maturities of available-for-sale securities	4,687	1,947
Net proceeds from the sales of other assets, and sales of and collections on notes receivable	59	29
Change in restricted cash	166	-27
Other	20	38
Net cash (used in) provided by investing activities	-3,566	-3,989
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Proceeds from the issuance of long-term debt	2,993	2,626
Proceeds from the issuance of common stock related to employee benefit plans	8	16
Payments for the redemption of long-term debt	-2,506	-1,934
Payments for the redemption of preferred stock	-96	0
Notes payable and commercial paper	537	98
Distributions to noncontrolling interests	-9	-14
Contributions from noncontrolling Interests	0	76
Dividends paid	-1,636	-1,211
Other	27	4
Net cash provided by (used in) financing activities	-682	-339
Net increase (decrease) in cash and cash equivalents	742	-349
Cash and cash equivalents at beginning of period	1,424	2,110
Cash and cash equivalents at end of period	2,166	1,761
Merger with Progress Energy [Abstract]	'	'
Fair value of assets acquired	'	48,698
Liabilities assumed	'	30,627
Issuance of common stock	'	18,071
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	383	407
Extinguishment of debt related to investment in Attiki Gas Supply, S.A.	'	66
Duke Energy Carolinas [Member]	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	767	735
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	865	860
Equity component of AFUDC	-70	-116
FERC mitigation costs	0	46
Community support and charitable contributions expense	14	59
(Gains) losses on sales of other assets	0	-9
Deferred income taxes	487	400
Voluntary opportunity cost deferral	0	-101
Accrued pension and other post-retirement benefit costs	29	32
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	-7	0
Receivables	-24	-28
Receivables from affiliated companies	-37	0
Inventory	23	-62
Other current assets	35	42
Increase (decrease) in [Abstract]	'	'
Accounts payable	-90	-152
Accounts payable to affiliated companies	107	-9
Taxes accrued	18	16
Other current liabilities	2	202
Other assets	-80	-53
Other liabilities	-66	-99
Net cash provided by (used in) operating activities	1,973	1,763
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-1,205	-1,453
Purchases of available-for-sale securities	-1,883	-672
Proceeds from sales and maturities of available-for-sale securities	1,847	644
Notes receivable from affiliated companies	-213	112
Other	-11	-6
Net cash (used in) provided by investing activities	-1,465	-1,375
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Proceeds from the issuance of long-term debt	0	645
Payments for the redemption of long-term debt	0	-752
Dividends to parent	-500	-250
Other	-2	-6
Net cash provided by (used in) financing activities	-502	-363
Net increase (decrease) in cash and cash equivalents	6	25
Cash and cash equivalents at beginning of period	19	289
Cash and cash equivalents at end of period	25	314
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	111	126
Progress Energy [Member]	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	479	373
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	764	678
Equity component of AFUDC	-39	-77
Severance expense	0	39
FERC mitigation costs	0	71
Community support and charitable contributions expense	20	40
(Gains) losses on sales of other assets	3	-21
Impairment of other long-lived assets	368	0
Deferred income taxes	384	257
Amounts to be refunded to customers	0	100
Accrued pension and other post-retirement benefit costs	158	137
Contributions to qualified pension plans	-27	-122
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	33	-12
Receivables	-219	-97
Receivables from affiliated companies	12	-24
Inventory	79	60
Other current assets	-102	-6
Increase (decrease) in [Abstract]	'	'
Accounts payable	-227	6
Accounts payable to affiliated companies	25	29
Taxes accrued	161	175
Other current liabilities	113	-15
Other assets	-223	0
Other liabilities	-64	-141
Net cash provided by (used in) operating activities	1,698	1,450
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-1,739	-1,695
Purchases of available-for-sale securities	-1,651	-947
Proceeds from sales and maturities of available-for-sale securities	1,630	921
Change in restricted cash	0	24
Notes receivable from affiliated companies	-103	0
Other	12	88
Net cash (used in) provided by investing activities	-1,851	-1,609
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Proceeds from the issuance of long-term debt	545	1,432
Proceeds from the issuance of common stock related to employee benefit plans	0	6
Payments for the redemption of long-term debt	-1,194	-961
Payments for the redemption of preferred stock	-96	0
Payments of short-term debt with original maturities greater than 90 days	0	-65
Proceeds from issuance of short-term debt with original maturities greater than 90 days	0	65
Notes payable and commercial paper	0	-671
Notes payable to affiliated companies	740	635
Distributions to noncontrolling interests	-2	-6
Dividends paid	0	-445
Other	-5	-4
Net cash provided by (used in) financing activities	-12	-14
Net increase (decrease) in cash and cash equivalents	-165	-173
Cash and cash equivalents at beginning of period	231	230
Cash and cash equivalents at end of period	66	57
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	199	250
Asset retirement obligation additions and estimate revisions	0	813
Capital expenditures financed through capital leases	0	137
Duke Energy Progress [Member]	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	362	180
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	507	499
Equity component of AFUDC	-33	-50
Severance expense	0	16
FERC mitigation costs	0	71
Community support and charitable contributions expense	20	40
(Gains) losses on sales of other assets	-1	-2
Impairment of other long-lived assets	22	0
Deferred income taxes	272	127
Accrued pension and other post-retirement benefit costs	74	58
Contributions to qualified pension plans	0	-60
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	-11	-33
Receivables	-75	-35
Receivables from affiliated companies	4	-10
Inventory	32	23
Other current assets	-41	-6
Increase (decrease) in [Abstract]	'	'
Accounts payable	-168	-20
Accounts payable to affiliated companies	0	23
Taxes accrued	63	62
Other current liabilities	-75	16
Other assets	-87	-19
Other liabilities	-77	-27
Net cash provided by (used in) operating activities	788	853
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-998	-1,098
Purchases of available-for-sale securities	-460	-385
Proceeds from sales and maturities of available-for-sale securities	438	359
Other	3	75
Net cash (used in) provided by investing activities	-1,017	-1,049
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Proceeds from the issuance of long-term debt	545	988
Payments for the redemption of long-term debt	-451	-502
Payments for the redemption of preferred stock	-62	0
Notes payable and commercial paper	0	-188
Notes payable to affiliated companies	217	212
Dividends to parent	0	-310
Dividends paid on preferred stock	0	-2
Other	-6	-3
Net cash provided by (used in) financing activities	243	195
Net increase (decrease) in cash and cash equivalents	14	-1
Cash and cash equivalents at beginning of period	18	20
Cash and cash equivalents at end of period	32	19
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	122	144
Asset retirement obligation additions and estimate revisions	0	684
Capital expenditures financed through capital leases	0	137
Duke Energy Florida [Member]	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	250	311
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	240	161
Equity component of AFUDC	-6	-27
Severance expense	0	7
(Gains) losses on sales of other assets	-1	-2
Impairment of other long-lived assets	346	0
Deferred income taxes	229	192
Amounts to be refunded to customers	0	100
Accrued pension and other post-retirement benefit costs	66	52
Contributions to qualified pension plans	-27	-61
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	37	64
Receivables	-127	-76
Receivables from affiliated companies	19	-12
Inventory	46	36
Other current assets	-132	-47
Increase (decrease) in [Abstract]	'	'
Accounts payable	30	68
Accounts payable to affiliated companies	-19	11
Taxes accrued	152	110
Other current liabilities	203	-15
Other assets	-128	21
Other liabilities	-44	-123
Net cash provided by (used in) operating activities	1,134	770
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-734	-573
Purchases of available-for-sale securities	-1,191	-562
Proceeds from sales and maturities of available-for-sale securities	1,192	561
Notes receivable from affiliated companies	177	0
Other	0	11
Net cash (used in) provided by investing activities	-556	-563
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Payments for the redemption of long-term debt	-435	-9
Payments for the redemption of preferred stock	-34	0
Payments of short-term debt with original maturities greater than 90 days	0	-65
Proceeds from issuance of short-term debt with original maturities greater than 90 days	0	65
Notes payable and commercial paper	0	-233
Notes payable to affiliated companies	0	213
Dividends to parent	-225	-170
Dividends paid on preferred stock	0	-1
Other	0	-3
Net cash provided by (used in) financing activities	-694	-203
Net increase (decrease) in cash and cash equivalents	-116	4
Cash and cash equivalents at beginning of period	131	16
Cash and cash equivalents at end of period	15	20
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	76	102
Asset retirement obligation additions and estimate revisions	0	129
Duke Energy Ohio [Member]	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	96	133
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	268	252
(Gains) losses on sales of other assets	-5	-2
Deferred income taxes	76	78
Accrued pension and other post-retirement benefit costs	12	8
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	0	18
Receivables	-6	40
Receivables from affiliated companies	1	51
Inventory	29	21
Other current assets	-8	17
Increase (decrease) in [Abstract]	'	'
Accounts payable	-56	-56
Accounts payable to affiliated companies	4	-16
Taxes accrued	-29	-49
Other current liabilities	10	-16
Other assets	3	-39
Other liabilities	-63	-73
Net cash provided by (used in) operating activities	332	367
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-318	-386
Net proceeds from the sales of other assets, and sales of and collections on notes receivable	11	82
Change in restricted cash	0	-46
Notes receivable from affiliated companies	-45	317
Other	1	1
Net cash (used in) provided by investing activities	-351	-32
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Proceeds from the issuance of long-term debt	450	0
Payments for the redemption of long-term debt	-257	-507
Notes payable to affiliated companies	-176	86
Other	-2	0
Net cash provided by (used in) financing activities	15	-421
Net increase (decrease) in cash and cash equivalents	-4	-86
Cash and cash equivalents at beginning of period	31	99
Cash and cash equivalents at end of period	27	13
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	20	26
Transfer of Vermillion Generating Station	'	28
Duke Energy Indiana [Member]	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'
Net income	276	-109
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	230	296
Equity component of AFUDC	-11	-61
Impairment of other long-lived assets	0	580
Deferred income taxes	190	-97
Accrued pension and other post-retirement benefit costs	19	12
(Increase) decrease in [Abstract]	'	'
Net realized and unrealized mark-to-market and hedging transactions	-31	0
Receivables	15	16
Receivables from affiliated companies	-19	23
Inventory	-33	-26
Other current assets	27	5
Increase (decrease) in [Abstract]	'	'
Accounts payable	-22	20
Accounts payable to affiliated companies	-7	-20
Taxes accrued	16	-35
Other current liabilities	-9	-7
Other assets	2	15
Other liabilities	-78	-28
Net cash provided by (used in) operating activities	565	584
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'
Capital expenditures	-387	-582
Purchases of available-for-sale securities	-7	-12
Proceeds from sales and maturities of available-for-sale securities	6	14
Notes receivable from affiliated companies	-69	0
Other	-4	-1
Net cash (used in) provided by investing activities	-461	-581
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'
Proceeds from the issuance of long-term debt	498	250
Payments for the redemption of long-term debt	-403	-4
Notes payable to affiliated companies	-81	-245
Dividends to parent	-125	0
Other	-4	-2
Net cash provided by (used in) financing activities	-115	-1
Net increase (decrease) in cash and cash equivalents	-11	2
Cash and cash equivalents at beginning of period	36	16
Cash and cash equivalents at end of period	25	18
Significant Non-cash Transactions [Abstract]	'	'
Accrued capital expenditures	36	37
Transfer of Vermillion Generating Station	$0	$26

Condensed_Consolidated_Stateme5

Condensed Consolidated Statements of Equity (Unaudited) (USD $)

Total

Common Stock [Member]

Additional Paid In Capital [Member]

Retained Earnings [Member]

Foreign Currency Adjustments [Member]

Net Gains (Losses) on Cash Flow Hedges [Member]

Net Gains (Losses) on Available for Sale Securities [Member]

Pension And OPEB Related Adjustments To AOCI [Member]

Common Stockholders' Equity [Member]

Noncontrolling Interest [Member]

Duke Energy Carolinas [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

In Millions, except Share data, unless otherwise specified

Members Equity [Member]

Net Gains (Losses) on Cash Flow Hedges [Member]

Net Gains (Losses) on Available for Sale Securities [Member]

Common Stock [Member]

Additional Paid In Capital [Member]

Retained Earnings [Member]

Net Gains (Losses) on Cash Flow Hedges [Member]

Pension And OPEB Related Adjustments To AOCI [Member]

Common Stockholders' Equity [Member]

Noncontrolling Interest [Member]

Common Stock [Member]

Retained Earnings [Member]

Net Gains (Losses) on Cash Flow Hedges [Member]

Common Stock [Member]

Retained Earnings [Member]

Net Gains (Losses) on Cash Flow Hedges [Member]

Pension And OPEB Related Adjustments To AOCI [Member]

Common Stock [Member]

Additional Paid In Capital [Member]

Retained Earnings [Member]

Pension And OPEB Related Adjustments To AOCI [Member]

Common Stock [Member]

Additional Paid In Capital [Member]

Retained Earnings [Member]

Net Gains (Losses) on Cash Flow Hedges [Member]

Balance at Dec. 31, 2011

($2)

$5,167

$762

$3,734

Transfer of Vermillion Generating Station

Ending Member's Equity at Jan. 12, 2012

Balance at Dec. 31, 2011

22,865

21,132

1,873

-45

-71

-9

-109

22,772

9,454

9,473

-17

-2

10,025

7,418

2,752

-142

-23

10,021

5,088

2,148

3,011

-71

4,675

1,757

2,945

-27

5,167

762

5,085

-652

-28

3,734

1,358

2,368

Balance (in shares) at Dec. 31, 2011

445,000,000

Net income

1,345

735

373

180

311

133

-109

Net income

1,344

[1]

1,333

370

368

[2]

Other comprehensive income (loss), net of tax

-110

-81

-19

-15

-106

-4

-1

Common stock issuances, including dividend reinvestment and employee benefits (in shares)

1,000,000

Common stock issuances, including dividend reinvestment and employee benefits

Common stock issued in connection with the Progress Energy Merger (in shares)

258,000,000

Common stock issued in connection with the Progress Energy Merger

18,071

Stock-based compensation expense

Common stock dividends

-1,211

-369

Dividends paid to parent

-250

-310

-170

Preferred stock dividends at stated rates

-2

-1

Changes in noncontrolling interest in subsidiaries

-4

[3]

-4

Transfer of Vermillion Generating Station

-28

Deconsolidation of DS Cornerstone, LLC

-82

[3]

-82

Contribution from noncontrolling interest in DS Cornerstone, LLC

[3]

Distributions to noncontrolling interests

-2

Recapitalization for merger with Duke Energy

-7,436

7,436

Tax dividend

-1

Other

-1

Notes To Reconciliation Of Total Equity [Details]

Net income attributable to preferred shareholders

Balance at Sep. 30, 2012

40,995

39,249

1,995

-126

-90

-124

40,905

9,941

9,958

-15

-2

10,153

7,465

2,751

-43

-23

10,150

5,038

2,159

2,879

4,845

1,762

3,084

-1

5,273

762

5,057

-519

-27

3,650

1,384

2,259

Balance (in shares) at Sep. 30, 2012

704,000,000

Beginning Member's Equity at Jun. 30, 2012

Net income

598

258

157

100

-19

Other comprehensive income (loss), net of tax

-20

Balance at Sep. 30, 2012

40,995

9,941

-2

10,153

5,038

4,845

5,273

762

3,650

Balance (in shares) at Sep. 30, 2012

704,000,000

Balance at Dec. 31, 2012

40,941

39,279

1,889

-116

-100

-90

40,863

9,888

-15

-1

10,185

7,465

2,783

-42

-25

10,181

5,127

2,159

2,968

4,799

1,762

3,037

5,166

762

4,882

-477

-1

3,708

1,384

2,318

Balance (in shares) at Dec. 31, 2012

704,000,000

100

160,000,000

100

89,663,086

53,913,701

Beginning Member's Equity at Dec. 31, 2012

9,872

Net income

1,984

767

479

362

250

276

Net income

1,977

479

477

Other comprehensive income (loss), net of tax

-78

-133

-2

-74

-4

-1

-2

Common stock issuances, including dividend reinvestment and employee benefits (in shares)

2,000,000

Common stock issuances, including dividend reinvestment and employee benefits

Common stock dividends

-1,636

Dividends paid to parent

-500

-225

-125

Premium on the redemption of preferred stock of subsidiaries

-3

-2

-1

Transfer of Vermillion Generating Station

Distributions to noncontrolling interests

-9

[4]

-9

-2

Notes To Reconciliation Of Total Equity [Details]

Net income attributable to preferred shareholders

Balance at Sep. 30, 2013

41,237

39,317

2,227

-249

-44

-2

-85

41,165

-14

-1

10,667

7,465

3,257

-39

-20

10,663

5,487

2,159

3,328

4,822

1,762

3,061

-1

5,263

762

4,882

-381

3,857

1,384

2,469

Balance (in shares) at Sep. 30, 2013

706,000,000

100

160,000,000

100

89,663,086

53,913,701

Ending Member's Equity at Sep. 30, 2013

10,140

10,155

Beginning Member's Equity at Jun. 30, 2013

Net income

1,008

342

175

197

104

Other comprehensive income (loss), net of tax

-4

-1

Balance at Sep. 30, 2013

41,237

-1

10,667

7,465

5,487

2,159

4,822

1,762

5,263

762

4,882

3,857

1,384

Balance (in shares) at Sep. 30, 2013

706,000,000

100

160,000,000

100

89,663,086

53,913,701

Ending Member's Equity at Sep. 30, 2013

$10,140

[1]

For the nine months ended September 30, 2012 consolidated net income of $1,345 million includes $1 million attributable to preferred shareholders of subsidiaries. Income attributable to preferred shareholders of subsidiaries is not a component of total equity and is excluded from the table above.

[2]

For the nine months ended September 30, 2012, consolidated net income of $373 million includes $3 million attributable to preferred shareholders of subsidiaries. Income attributable to preferred shareholders of subsidiaries is not a component of total equity and is excluded from the table above.

[3]

Refer to Note 2 for further information related to DS Cornerstone, LLC.

[4]

Includes payments to noncontrolling interests of $14 million for the nine months ended September 30, 2012.

Organization_and_Basis_of_Pres

Organization and Basis of Presentation

9 Months Ended

Sep. 30, 2013

Organization And Basis of Presentation [Abstract]

Organization and Basis of Presentation

Index to Combined Notes To Condensed Consolidated Financial Statements

The unaudited notes to the condensed consolidated financial statements that follow are a combined presentation. The following list indicates the registrants to which the footnotes apply.

Applicable Notes

Registrant

Duke Energy Corporation

•

Duke Energy Carolinas, LLC

•

Progress Energy, Inc.

•

Duke Energy Progress, Inc.

•

Duke Energy Florida, Inc.

•

Duke Energy Ohio, Inc.

•

Duke Energy Indiana, Inc.

•

1. ORGANIZATION AND BASIS OF PRESENTATION

NATURE OF OPERATIONS AND BASIS OF CONSOLIDATION

Duke Energy Corporation (collectively with its subsidiaries, Duke Energy), is an energy company headquartered in Charlotte, North Carolina, subject to regulation by the Federal Energy Regulatory Commission (FERC). Duke Energy operates in the United States (U.S.) and Latin America primarily through its direct and indirect subsidiaries. Duke Energy's subsidiaries include its subsidiary registrants, Duke Energy Carolinas, LLC (Duke Energy Carolinas); Progress Energy, Inc. (Progress Energy); Duke Energy Progress, Inc. (Duke Energy Progress); Duke Energy Florida, Inc. (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, Inc. (Duke Energy Indiana). When discussing Duke Energy's consolidated financial information, it necessarily includes the results of its six separate subsidiary registrants (collectively referred to as the Subsidiary Registrants), which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.

As discussed in the combined Annual Report on Form 10-K for the year ended December 31, 2012, Duke Energy merged with Progress Energy on July 2, 2012. Accordingly, Duke Energy's consolidated financial statements include Progress Energy, Duke Energy Progress and Duke Energy Florida activity beginning July 2, 2012. See Note 2 for additional information regarding the merger.

The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes. However, none of the registrants makes any representation as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself. As discussed further in Note 3, Duke Energy operates three reportable business segments: U.S. Franchised Electric and Gas (USFE&G), Commercial Power and International Energy. The remainder of Duke Energy's operations is presented as Other.

These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and all majority-owned subsidiaries where the respective Duke Energy Registrants have control and those variable interest entities (VIEs) where the respective Duke Energy Registrants are the primary beneficiary. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants' proportionate share of certain generation and transmission facilities.

Duke Energy Carolinas, a wholly owned subsidiary of Duke Energy, is a regulated public utility that generates, transmits, distributes and sells electricity in portions of North Carolina and South Carolina. Duke Energy Carolinas is subject to the regulatory provisions of the North Carolina Utilities Commission (NCUC), the Public Service Commission of South Carolina (PSCSC), the U.S. Nuclear Regulatory Commission (NRC), and the FERC. Substantially all of Duke Energy Carolinas' operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Carolinas' operations include one reportable business segment, Franchised Electric.

Progress Energy, a wholly owned subsidiary of Duke Energy, is a holding company headquartered in Raleigh, North Carolina, subject to regulation by the FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida. As discussed further in Note 3, Progress Energy's operations include one reportable segment, Franchised Electric.

Duke Energy Progress, an indirect wholly owned subsidiary of Duke Energy, is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Progress is subject to the regulatory provisions of the NCUC, the PSCSC, the NRC, and the FERC. Substantially all of Duke Energy Progress' operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Progress' operations include one reportable segment, Franchised Electric.

Duke Energy Florida, an indirect wholly owned subsidiary of Duke Energy, is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Florida. Duke Energy Florida is subject to the regulatory provisions of the Florida Public Service Commission (FPSC), the NRC, and the FERC. Substantially all of Duke Energy Florida's operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Florida's operations include one reportable segment, Franchised Electric.

Duke Energy Ohio, an indirect wholly owned subsidiary of Duke Energy, is a combination electric and gas public utility that provides service in portions of Ohio and Kentucky. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). Duke Energy Ohio also generates electricity in portions of Ohio, Illinois and Pennsylvania. Duke Energy Ohio's principal lines of business include generation, transmission and distribution of electricity, the sale of and/or transportation of natural gas, and energy marketing. Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers. Duke Energy Kentucky's principal lines of business include generation, transmission and distribution of electricity, as well as the sale of and/or transportation of natural gas. References herein to Duke Energy Ohio include Duke Energy Ohio and its subsidiaries, unless otherwise noted. Duke Energy Ohio is subject to the regulatory provisions of the Public Utilities Commission of Ohio (PUCO), the Kentucky Public Service Commission (KPSC), and the FERC. Duke Energy Ohio applies regulatory accounting treatment to substantially all of the operations in its Franchised Electric and Gas operating segment. See Note 3 for further information about Duke Energy Ohio's business segments.

Duke Energy Indiana, an indirect wholly owned subsidiary of Duke Energy, is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Indiana. Duke Energy Indiana is subject to the regulatory provisions of the Indiana Utility Regulatory Commission (IURC) and the FERC. Substantially all of Duke Energy Indiana's operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Indiana's operations include one reportable business segment, Franchised Electric.

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. Because the interim Condensed Consolidated Financial Statements and Notes do not include all information and notes required by GAAP in the U.S. for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the Consolidated Financial Statements and Notes in the Duke Energy Registrants' combined Annual Report on Form 10-K for the year ended December 31, 2012.

These Condensed Consolidated Financial Statements reflect all normal recurring adjustments in the opinion of the respective companies' management, necessary to fairly present the financial position and results of operations of each of the Duke Energy Registrants. Amounts reported in Duke Energy's interim Condensed Consolidated Statements of Operations and each of the Subsidiary Registrants' interim Condensed Consolidated Statements of Income and Comprehensive Income are not necessarily indicative of amounts expected for the respective annual periods due to effects of seasonal temperature variations on energy consumption, regulatory rulings, timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, and other factors.

In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.

UNBILLED REVENUE

Revenues on sales of electricity and gas are recognized when either the service is provided or the product is delivered. Unbilled revenues are estimated by applying an average rate for retail customers or a contract rate for wholesale customers by the estimated volume of energy delivered but not billed. The amount of unbilled revenues can vary significantly from period to period as a result of numerous factors, including seasonality, weather, customer usage patterns and customer mix.

The Duke Energy Registrants had unbilled revenues within Receivables and within Restricted receivables of variable interest entities on their respective Condensed Consolidated Balance Sheets as shown in the table below.

(in millions)

30-Sep-13

31-Dec-12

Duke Energy

856

920

Duke Energy Carolinas

288

315

Progress Energy

220

187

Duke Energy Progress

120

112

Duke Energy Florida

100

Duke Energy Ohio

Duke Energy Indiana

Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail and wholesale accounts receivable to Cinergy Receivables Company, LLC (CRC). These transfers meet sales/derecognition criteria and, therefore, Duke Energy Ohio and Duke Energy Indiana account for the transfers of receivables to CRC as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. Receivables for unbilled revenues related to retail and wholesale accounts receivable at Duke Energy Ohio and Duke Energy Indiana included in the sales of accounts receivable to CRC were as shown in the table below.

(in millions)

30-Sep-13

31-Dec-12

Duke Energy Ohio

Duke Energy Indiana

126

132

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS

Income From Discontinued Operations, net of tax presented on the respective Condensed Consolidated Statements of Operations for Duke Energy and Progress Energy is attributable only to controlling interests for all periods presented. Other comprehensive income reported on the respective Condensed Consolidated Statements of Equity for Duke Energy and Progress Energy is attributable only to controlling interests for all periods presented.

ACCUMULATED OTHER COMPREHENSIVE INCOME

For the three and nine months ended September 30, 2013, reclassifications out of accumulated other comprehensive income (AOCI) for the Duke Energy Registrants were not material. For the three and nine months ended September 30, 2012, Progress Energy, Duke Energy Progress and Duke Energy Florida reclassified pretax losses on open derivative contracts from AOCI to Regulatory Assets as disclosed in Note 8. Reclassifications out of AOCI for other Duke Energy Registrants were not material for the three and nine months ended September 30, 2012. Changes in AOCI for the Duke Energy Registrants are presented in their respective Condensed Consolidated Statements of Equity.

Acquisitions_and_Sales_of_Othe

Acquisitions and Sales of Other Assets	9 Months Ended
Acquisitions and Sales of Other Assets	Sep. 30, 2013
Acquisitions And Sales Of Other Assets [Abstract]	'
Acquisitions And Sales Of Other Assets	'
	2. ACQUISITIONS AND DISPOSITIONS
	ACQUISITIONS
	The Duke Energy Registrants consolidate assets and liabilities from acquisitions as of the purchase date, and include earnings from acquisitions in consolidated earnings beginning on the purchase date.
	Merger with Progress Energy
	On July 2, 2012, Duke Energy completed its merger with Progress Energy, a North Carolina corporation engaged in the regulated utility business of generation, transmission and distribution and sale of electricity in portions of North Carolina, South Carolina and Florida. As a result of the merger, Progress Energy became a wholly owned subsidiary of Duke Energy.
	Purchase Price
	All Progress Energy common shares were exchanged at the fixed exchange ratio of 0.87083 common shares of Duke Energy. The total consideration transferred of $18,071 million, including $62 million fair value of stock-based compensation awards, was based on the closing price of Duke Energy common shares on July 2, 2012. The significant assets and liabilities recorded at fair values as of the acquisition date include the acquired long-term debt, asset retirement obligations, capital leases and pension and other post-retirement benefit (OPEB) plans.
	The fair value of assets acquired and liabilities assumed was determined based on significant estimates and assumptions, including Level 3 inputs, which are judgmental in nature. The estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in the future cash flows, and future market prices.
	Additionally the February 5, 2013 announcement of the decision to retire Crystal River Nuclear Station - Unit 3 (Crystal River Unit 3), reflects additional information related to facts and circumstances existing as of the acquisition date. See Note 4 for additional information related to Crystal River Unit 3. As such, Duke Energy presents the assets acquired and liabilities assumed as if the retirement of Crystal River Unit 3 occurred on the acquisition date.
	The majority of Progress Energy's operations are subject to the rate-setting authority of the FERC, NCUC, PSCSC, and FPSC and are accounted for pursuant to U.S. GAAP, including the accounting guidance for regulated operations. The rate-setting and cost recovery provisions currently in place for Progress Energy's regulated operations provide revenues derived from costs, including a return on investment of assets and liabilities included in rate base. Except for long-term debt, asset retirement obligations, capital leases, pension and OPEB plans, and the wholesale portion of Duke Energy Florida's Crystal River Unit 3, the fair values of tangible and intangible assets and liabilities subject to these rate-setting provisions approximate their carrying values. Accordingly, the assets and liabilities acquired and pro forma financial information do not reflect any net adjustments related to these amounts. The difference between fair value and the pre-merger carrying amounts for long-term debt, asset retirement obligations, capital leases and pension and OPEB plans for the regulated operations were recorded as Regulatory assets.
	The excess of the purchase price over the estimated fair values of assets acquired and liabilities assumed was recognized as goodwill at the acquisition date. The goodwill reflects the value paid primarily for the long-term potential for enhanced access to capital as a result of the company's increased scale and diversity, opportunities for synergies, and an improved risk profile. The goodwill resulting from the merger was allocated entirely to the USFE&G segment. None of the goodwill recognized is deductible for income tax purposes, and as such, no deferred taxes have been recorded related to goodwill.
	The completed purchase price allocation of the merger is presented in the following table.

	(in millions)
	Current assets	$	3,204
	Property, plant and equipment		23,141
	Goodwill		12,469
	Other long-term assets, excluding goodwill		9,990
	Total assets		48,804
	Current liabilities, including current maturities of long-term debt		3,593
	Long-term liabilities, preferred stock and noncontrolling interests		10,394
	Long-term debt		16,746
	Total liabilities and preferred stock		30,733
	Total purchase price	$	18,071

	The purchase price allocation in the table above reflects refinements made to the preliminary fair values of assets acquired and liabilities assumed included in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2012. These refinements include adjustments associated with the retirement of Crystal River Unit 3. The changes resulted in an increase to Goodwill of $2 million, an increase to the fair value of Current liabilities, including Current maturities of long-term debt of $12 million, a decrease to Property, plant and equipment of $138 million, a decrease to Other long-term assets, excluding goodwill of $4 million and a decrease to Long-term liabilities, preferred stock and noncontrolling interests of $152 million. These refinements had no impact on the amortization of the purchase accounting adjustments recorded to earnings during 2012 or for the three and nine months ended September 30, 2013.
	Pro Forma Financial Information
	The following unaudited pro forma financial information reflects the consolidated results of operations of Duke Energy for the three and nine months ended September 30, 2012. This information reflects the amortization of purchase price adjustments assuming the merger had taken place on January 1, 2011. The unaudited pro forma financial information has been presented for illustrative purposes only and is not necessarily indicative of the consolidated results of operations that would have been achieved or the future consolidated results of operations of Duke Energy.
	Non-recurring merger consummation, integration and other costs incurred by Duke Energy and Progress Energy during the three and nine months ended September 30, 2012 have been excluded from the pro forma earnings presented below. After-tax non-recurring merger consummation, integration and other costs incurred by both Duke Energy and Progress Energy were $293 million and $322 million for the three and nine months ended September 30, 2012. The pro forma financial information also excludes potential future cost savings or non-recurring charges related to the merger.

	(in millions, except per share amounts)	Three Months Ended September 30, 2012		Nine Months Ended September 30, 2012
	Revenues	$	6,727	$	18,309
	Net Income Attributable to Duke Energy Corporation		889		1,888
	Basic and Diluted Earnings Per Share		1.26		2.68

	Chilean Hydro Acquisition
	In December 2012, International Energy acquired Iberoamericana de Energía Ibener, S.A. (Ibener) of Santiago, Chile for cash consideration of $415 million. This acquisition included the 140 megawatt (MW) Duqueco hydroelectric generation complex consisting of two run-of-the-river plants located in southern Chile. The preliminary purchase accounting entries consisted primarily of $383 million of property, plant and equipment, $30 million of intangible assets, $57 million of deferred income tax liabilities, $54 million of goodwill, and $6 million of working capital. The fair value of assets acquired and liabilities assumed utilized for the purchase price allocation are preliminary and subject to revision until the valuations are completed and to the extent that additional information is obtained about facts and circumstances existing as of the acquisition date. In April 2013, the six-month bridge loan executed in connection with the acquisition was replaced with a nonrecourse secured credit facility with a term of thirteen years, and $192 million of cash collateral related to the six-month bridge loan was returned to Duke Energy. See Note 6, “Debt and Credit Facilities,” for additional discussion related to the bridge loan conversion.
	Vermillion Generating Station
	On January 12, 2012, after receiving approvals from the FERC and the IURC, Duke Energy Vermillion II, LLC (Duke Energy Vermillion), an indirect wholly owned subsidiary of Duke Energy Ohio, completed the sale of its 75 percent undivided ownership interest in the Vermillion Generating Station (Vermillion) to Duke Energy Indiana and Wabash Valley Power Association (WVPA). Upon the closing of the sale, Duke Energy Indiana held a 62.5 percent interest and WVPA held a 37.5 percent interest in Vermillion. Duke Energy Ohio received net proceeds of $82 million, consisting of $68 million From Duke Energy Indiana and $14 million from WVPA.
	As Duke Energy Indiana is an affiliate of Duke Energy Vermillion, the transaction has been accounted for as a transfer between entities under common control. As a result, no gain or loss was recorded and the transaction did not have a significant impact to Duke Energy Ohio or Duke Energy Indiana's results of operations. The proceeds received from Duke Energy Indiana are included in Net proceeds from the sales of other assets on Duke Energy Ohio's Condensed Consolidated Statements of Cash Flows. The cash paid to Duke Energy Ohio is included in Capital expenditures on Duke Energy Indiana's Condensed Consolidated Statements of Cash Flows. The transaction resulted in the recognition of non-cash after-tax equity transfers of $28 million for Duke Energy Ohio and $26 million for Duke Energy Indiana. These transfers are recorded in Duke Energy Ohio's and Duke Energy Indiana's Condensed Consolidated Statements of Equity and represent the difference between cash exchanged and the net book value of Vermillion. These amounts are not reflected in Duke Energy's Condensed Consolidated Statements of Cash Flows or Condensed Consolidated Statements of Equity as the transaction is eliminated in consolidation.
	The proceeds from WVPA are included in Net proceeds from the sales of other assets, and sale of and collections on notes receivable on Duke Energy and Duke Energy Ohio's Condensed Consolidated Statements of Cash Flows. The sale of the proportionate share of Vermillion to WVPA did not result in a significant gain or loss.
	DISPOSITIONS
	DukeNet Communications
	On October 4, 2013, Duke Energy, together with investment funds managed by Alinda, agreed to sell their interest in DukeNet Communications, LLC (DukeNet) to Time Warner Cable, Inc. Following the repayment of existing DukeNet indebtedness at closing, estimated transaction expenses and other purchase price adjustments, Duke Energy expects to receive cash proceeds of approximately $210 million. The transaction is expected to close in the first quarter of 2014, subject to customary closing conditions, including receipt of required regulatory approvals.
	Wind Projects Joint Venture
	In April 2012, Duke Energy executed a joint venture agreement with Sumitomo Corporation of America (SCOA). Under the terms of the agreement, Duke Energy and SCOA each own a 50 percent interest in the joint venture (DS Cornerstone, LLC), which owns two wind generation projects. The facilities began commercial operations in June 2012 and August 2012. Duke Energy and SCOA also negotiated a $330 million, Construction and 12-year amortizing Term Loan Facility, on behalf of the borrower, a wholly owned subsidiary of the joint venture. The loan agreement is non-recourse to Duke Energy. Duke Energy received proceeds of $319 million upon execution of the loan agreement. This amount represents reimbursement of a significant portion of Duke Energy's construction costs incurred as of the date of the agreement.

Business_Segments

Business Segments	9 Months Ended
Business Segments	Sep. 30, 2013
Business Segments [Abstract]	'
Business Segments	'
	3. BUSINESS SEGMENTS
	Management evaluates segment performance based on Segment Income, which is defined as income from continuing operations net of income attributable to noncontrolling interests. Segment Income includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements. Certain governance costs are allocated to each segment. In addition, direct interest expense and income taxes are included in Segment Income.
	Operating segments for the Duke Energy Registrants are determined based on information used by the chief operating decision maker in deciding how to allocate resources and evaluate the performance at each of the Duke Energy Registrants.
	Products and services are sold between affiliate companies and between reportable segments at cost. Segment assets as presented in the tables that follow exclude all intercompany assets.
	DUKE ENERGY
	Duke Energy has three reportable operating segments: USFE&G, Commercial Power and International Energy.
	USFE&G generates, transmits, distributes and sells electricity in portions of North Carolina, South Carolina, Florida, Indiana, and Kentucky. USFE&G also transmits and distributes electricity in portions of Ohio. Additionally, USFE&G transports and sells natural gas in portions of Ohio and Kentucky. It conducts operations primarily through Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, certain regulated portions of Duke Energy Ohio, and Duke Energy Indiana. Segment information for USFE&G includes the results of the regulated operations of Duke Energy Progress and Duke Energy Florida beginning July 2, 2012.
	Commercial Power operates and manages power plants owned by Duke Energy Ohio and engages in the wholesale marketing and procurement of electricity, fuel and emission allowances related to these plants, as well as other contractual positions. Commercial Power also has a retail sales subsidiary, Duke Energy Retail Sales, LLC (Duke Energy Retail). Duke Energy Retail is certified by the PUCO as a Competitive Retail Electric Service provider. Through Duke Energy Generation Services, Inc. and its affiliates (DEGS), Commercial Power engages in the development, construction and operation of renewable energy and commercial transmission projects in the U.S.
	International Energy principally operates and manages power generation facilities and engages in sales and marketing of electricity and natural gas outside the U.S. It conducts operations primarily through Duke Energy International, LLC and its affiliates. Its activities principally target power generation in Latin America. Additionally, International Energy owns a 25 percent interest in National Methanol Company (NMC). Located in Saudi Arabia, NMC is a large regional producer of methanol and methyl tertiary butyl ether (MTBE).
	The remainder of Duke Energy's operations is presented as Other. While it is not considered an operating segment, Other primarily includes unallocated corporate costs, which primarily consist of interest expense on corporate debt instruments, costs to achieve mergers and divestitures, and costs associated with certain corporate severance programs. It also includes Bison Insurance Company Limited (Bison), a wholly owned, captive insurance subsidiary, Duke Energy's 50 percent interest in DukeNet and related telecommunications businesses, and Duke Energy's 60 percent interest in Duke Energy Trading and Marketing, LLC.

			Three Months Ended September 30, 2013
	(in millions)		USFE&G			International Energy			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
	Unaffiliated revenues^(a)(b)(c)		$	5,768		$	370		$	541		$	6,679		$	30		$	―		$	6,709
	Intersegment revenues			18			―			9			27			24			-51			―
		Total revenues	$	5,786		$	370		$	550		$	6,706		$	54		$	-51		$	6,709
	Segment income^(a)(b)(c)(d)		$	923		$	116		$	27		$	1,066		$	-76		$	―		$	990
	Add back noncontrolling interests component																					4
	Income from discontinued operations, net of tax																					14
	Net income																				$	1,008
	Segment assets as of September 30, 2013		$	99,269		$	5,669		$	6,852		$	111,790		$	2,658		$	142		$	114,590

	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(b)	In June 2013, Duke Energy Progress implemented revised customer rates approved by the NCUC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(c)	In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(d)	Other includes after-tax costs to achieve the merger with Progress Energy of $54 million. See Note 2 for additional information about the merger.


			Three Months Ended September 30, 2012
	(in millions)		USFE&G			International Energy			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
	Unaffiliated revenues		$	5,830		$	382		$	508		$	6,720		$	2		$	―		$	6,722
	Intersegment revenues			12			―			17			29			18			-47			―
		Total revenues	$	5,842		$	382		$	525		$	6,749		$	20		$	-47		$	6,722
	Segment income^(a)(b)		$	790		$	103		$	12		$	905		$	-315		$	―		$	590
	Add back noncontrolling interests component																					4
	Income from discontinued operations, net of tax																					4
	Net income																				$	598

	(a)	USFE&G recorded an impairment related to the Edwardsport Integrated Gasification Combined Cycle (IGCC) project. See Note 4 for additional information on the Edwardsport impairment.
	(b)	Other includes after-tax costs to achieve the merger with Progress Energy of $293 million. See Note 2 for additional information about the merger.


			Nine Months Ended September 30, 2013
	(in millions)		USFE&G			International Energy			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
	Unaffiliated revenues^(a)(b)(c)		$	15,731		$	1,168		$	1,527		$	18,426		$	60		$	―		$	18,486
	Intersegment revenues			35			―			32			67			65			-132			―
		Total revenues	$	15,766		$	1,168		$	1,559		$	18,493		$	125		$	-132		$	18,486
	Segment income^{(a)(b)(c)(d)(e)(f)}		$	1,932		$	300		$	26		$	2,258		$	-292		$	―		$	1,966
	Add back noncontrolling interests component																					7
	Income from discontinued operations, net of tax																					11
	Net income																				$	1,984

	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(b)	In June 2013, Duke Energy Progress implemented revised customer rates approved by the NCUC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(c)	In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(d)	USFE&G recorded an impairment charge related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information about the Crystal River Unit 3 impairment.
	(e)	USFE&G recorded an impairment charge related to Duke Energy Progress' Shearon Harris Nuclear Station (Harris) site. USFE&G also recorded an impairment charge related to Duke Energy Florida's proposed Levy Nuclear Station (Levy). See Note 4 for additional information about the Harris site and Levy site impairments.
	(f)	Other includes after-tax costs to achieve the merger with Progress Energy of $139 million. See Note 2 for additional information about the merger.


			Nine Months Ended September 30, 2012
	(in millions)		USFE&G			International Energy			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
	Unaffiliated revenues		$	11,178		$	1,181		$	1,560		$	13,919		$	10		$	―		$	13,929
Intersegment revenues			29			―			47			76			41			-117			―
	Total revenues	$	11,207		$	1,181		$	1,607		$	13,995		$	51		$	-117		$	13,929
Segment income^(a)(b)		$	1,263		$	350		$	71		$	1,684		$	-356		$	―		$	1,328
Add back noncontrolling interests component																					12
Income from discontinued operations, net of tax																					5
Net income																				$	1,345

(a)	USFE&G recorded an impairment charge related to Duke Energy Indiana's IGCC project. USFE&G also recorded the reversal of expenses of $60 million related to a prior year Voluntary Opportunity Plan in accordance with Duke Energy Carolinas' 2011 rate case. See Note 4 for additional information about the impairment charges.
(b)	Other includes after-tax costs to achieve the merger with Progress Energy of $306 million. See Note 2 for additional information about the merger.

DUKE ENERGY OHIO
Duke Energy Ohio has two reportable operating segments, Franchised Electric and Gas and Commercial Power.
Franchised Electric and Gas transmits and distributes electricity in portions of Ohio and generates, transmits, distributes and sells electricity in portions of Kentucky. Franchised Electric and Gas also transports and sells natural gas in portions of Ohio and Kentucky.
Commercial Power owns, operates and manages power plants and engages in the wholesale marketing and procurement of electricity, fuel, and emission allowances related to these plants, as well as other contractual positions. Duke Energy Ohio's Commercial Power reportable operating segment does not include the operations of DEGS or Duke Energy Retail, which are included in the Commercial Power reportable operating segment at Duke Energy.
The remainder of Duke Energy Ohio's operations is presented as Other. While not considered a reportable segment for Duke Energy Ohio, Other consists of costs to achieve the merger between Duke Energy and Progress Energy, certain corporate severance programs, and certain costs for use of corporate assets allocated to each company. See Note 17 for additional information. All of Duke Energy Ohio's revenues are generated domestically and its long-lived assets are all in the U.S.

		Three Months Ended September 30, 2013
(in millions)		Franchised Electric and Gas			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
Unaffiliated revenues^(a)		$	421		$	398		$	819		$	―		$	―		$	819
Intersegment revenues			―			6			6			―			-6			―
	Total revenues	$	421		$	404		$	825		$	―		$	-6		$	819
Segment income / Consolidated net income^(a)		$	42		$	30		$	72		$	-13		$	―		$	59
Segment assets as of September 30, 2013		$	6,631		$	4,088		$	10,719		$	103		$	-165		$	10,657

(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts FE&G. See Note 4 for additional information about the revised customer rates.

		Three Months Ended September 30, 2012
(in millions)		Franchised Electric and Gas			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
Unaffiliated revenues		$	431		$	326		$	757		$	―		$	―		$	757
Intersegment revenues			―			15			15			―			-15			―
	Total revenues	$	431		$	341		$	772		$	―		$	-15		$	757
Segment income (loss) / Consolidated net income		$	49		$	-17		$	32		$	-18		$	―		$	14

		Nine Months Ended September 30, 2013
(in millions)		Franchised Electric and Gas			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
Unaffiliated revenues^(a)		$	1,317		$	1,060		$	2,377		$	―		$	―		$	2,377
Intersegment revenues			―			25			25			―			-25			―
	Total revenues	$	1,317		$	1,085		$	2,402		$	―		$	-25		$	2,377
Segment income (loss) / Consolidated net income^(a)		$	122		$	-3		$	119		$	-23		$	―		$	96

(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts FE&G. See Note 4 for additional information about the revised customer rates.

		Nine Months Ended September 30, 2012
(in millions)		Franchised Electric and Gas			Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated
Unaffiliated revenues		$	1,291		$	1,095		$	2,386		$	―		$	―		$	2,386
Intersegment revenues			―			42			42			―			-42			―
	Total revenues	$	1,291		$	1,137		$	2,428		$	―		$	-42		$	2,386
Segment income / Consolidated net income		$	113		$	44		$	157		$	-24		$	―		$	133

DUKE ENERGY CAROLINAS, PROGRESS ENERGY, DUKE ENERGY PROGRESS, DUKE ENERGY FLORIDA AND DUKE ENERGY INDIANA
Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana each have one reportable operating segment, Franchised Electric, which generates, transmits, distributes and sells electricity. The remainder of each company's operations is classified as Other. While not considered a reportable segment for any of these companies, Other consists of costs to achieve the merger between Duke Energy and Progress Energy, certain corporate severance programs, and certain costs for use of corporate assets allocated to each company. See Note 17 for additional information. Other for Progress Energy also includes interest expense on corporate debt instruments. The following table summarizes the net loss for Other at each of these registrants.

			Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)			2013			2012			2013			2012
Duke Energy Carolinas			$	-26		$	-119		$	-69		$	-137
Progress Energy				-72			-181			-205			-278
Duke Energy Progress				-20			-109			-40			-119
Duke Energy Florida				-6			-23			-18			-30
Duke Energy Indiana				-5			-14			-13			-19

The Franchised Electric operating segments includes substantially all of Duke Energy Carolinas', Progress Energy's, Duke Energy Progress', Duke Energy Florida's and Duke Energy Indiana's assets.

Regulatory_Matters

Regulatory Matters

9 Months Ended

Sep. 30, 2013

Regulatory Matters [Abstract]

Regulatory Matters

4. REGULATORY MATTERS

RATE RELATED INFORMATION

The NCUC, PSCSC, FPSC, IURC, PUCO and KPSC approve rates for retail electric and gas services within their states. Nonregulated sellers of gas and electric generation are also allowed to operate in Ohio once certified by the PUCO. The FERC approves rates for electric sales to wholesale customers served under cost-based rates, as well as sales of transmission service.

Duke Energy Carolinas

2013 North Carolina Rate Case

On September 24, 2013, the NCUC approved a settlement agreement related to Duke Energy Carolinas' request for a rate increase with minor modifications. The North Carolina Utilities Commission Public Staff (Public Staff) was a party to the settlement agreement. The parties have agreed to a three year step-in rate increase, with the first two years providing for $205 million, or a 4.5 percent average increase in rates, and the third year providing for rates to be increased by an additional $30 million, or 0.6 percent. The agreement is based upon a return on equity of 10.2 percent and an equity component of the capital structure of 53 percent. The settlement agreement (i) allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) a $10 million shareholder contribution to agencies that provide energy assistance to low-income customers, and (iii) an annual reduction in the regulatory liability for costs of removal of $30 million for each of the first two years. Duke Energy Carolinas also agreed not to request additional base rate increases to be effective before September 2015. New rates went into effect on September 25, 2013.

On October 23, 2013, the North Carolina Attorney General (NCAG) appealed the rate of return and capital structure approved in the agreement. On October 24, 2013, the NC Waste Awareness and Reduction Network (NC WARN) also appealed various matters in the settlement. Duke Energy Carolinas cannot predict the outcome of this matter.

2013 South Carolina Rate Case

On September 11, 2013, the PSCSC approved a settlement agreement related to Duke Energy Carolinas' request for a rate increase. Parties to the settlement agreement were the Office of Regulatory Staff, Wal-Mart Stores East, LP and Sam's East, Incorporated, the South Carolina Energy Users Committee, Public Works of the City of Spartanburg, South Carolina and the South Carolina Small Business Chamber of Commerce. The parties agreed to a two year step-in rate increase, with the first year providing for approximately $80 million, or a 5.5 percent average increase in rates, and the second year providing for rates to be increased by an additional $38 million, or 2.6 percent. The settlement agreement is based upon a return on equity of 10.2 percent and a 53 percent equity component of the capital structure. The settlement agreement (i) allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) approximately $4 million of contributions to agencies that provide energy assistance to low-income customers and for economic development, and (iii) a reduction in the regulatory liability for costs of removal of $45 million for the first year. Duke Energy Carolinas also agreed not to request additional base rate increases to be effective before September 2015. New rates went into effect on September 18, 2013.

2011 North Carolina Rate Case

On January 27, 2012, the NCUC approved a settlement agreement related to Duke Energy Carolinas' request for a rate increase. The Public Staff was a party to the settlement. On March 28, 2012, the NCAG appealed the rate of return approved in the agreement. On April 12, 2013, the North Carolina Supreme Court (NCSC) ordered the NCUC to make an independent determination regarding the proper return on equity. The NCSC stated the determination should be based upon appropriate findings of fact that weigh all the available evidence, including the impact of changing economic conditions on customers. On October 23, 2013, the NCUC reaffirmed the rate of return approved in the January 27, 2012 settlement agreement. On October 25, 2013, the NCAG announced his intention to appeal the reaffirmed order. The appeal has not yet been filed. Duke Energy Carolinas cannot predict the outcome of this matter.

V.C. Summer Nuclear Station Letter of Intent

In July 2011, Duke Energy Carolinas signed a letter of intent with Santee Cooper related to the potential acquisition by Duke Energy Carolinas of a 5 percent to 10 percent ownership interest in the V.C. Summer Nuclear Station being developed by Santee Cooper and South Carolina Electric and Gas (SCE&G) near Jenkinsville, South Carolina. The letter of intent provided a path for Duke Energy Carolinas to conduct the necessary due diligence to determine whether future participation in this project is beneficial for its customers. On November 7, 2012, the letter of intent expired. However, Duke Energy Carolinas remains engaged in discussions at this time.

William States Lee III Nuclear Station

In December 2007, Duke Energy Carolinas applied to the NRC for a Combined Construction and Operating License (COL) for two Westinghouse AP1000 (advanced passive) reactors for the proposed William States Lee III Nuclear Station (Lee Nuclear Station) at a site in Cherokee County, South Carolina. Submitting the COL application does not commit Duke Energy Carolinas to build nuclear units. Through several separate orders, the NCUC and PSCSC have concurred with the prudency of Duke Energy Carolinas incurring certain project development and pre-construction costs, although recovery of costs is not guaranteed. Duke Energy Carolinas has incurred approximately $370 million, including allowance for funds used during construction (AFUDC) through September 30, 2013. This amount is included in Net property, plant and equipment on Duke Energy Carolinas' Condensed Consolidated Balance Sheets.

The Lee COL application is impacted by the ongoing NRC activity to address its Waste Confidence rule. The Waste Confidence rule is a generic finding by the NRC that spent fuel can be managed safely until ultimate disposal. The U.S. Court of Appeals for the District of Columbia (D.C. Circuit) remanded the rule to the NRC. The NRC determined that no final licenses for new reactors would be issued until the remand is appropriately addressed. Based upon current timelines from the NRC, licenses would not be issued until September 2014 at the earliest. The COL is also impacted by the time required to fully respond to an NRC request for additional information addressing seismic hazard evaluation resulting from recommendations of the Fukushima Near-Term Task Force. Due to the schedule for both fully responding and for NRC review of the response, the Lee COL is not expected until 2016.

Duke Energy Progress

2012 North Carolina Rate Case

On May 30, 2013, the NCUC approved a settlement agreement related to Duke Energy Progress' request for a rate increase. The Public Staff was a party to the settlement agreement. The parties have agreed to a two year step-in rate increase, with the first year providing for a $147 million, or a 4.5 percent average increase in rates, and the second year providing for rates to be increased by an additional $31 million, or a 1.0 percent average increase in rates. The second year increase is a result of Duke Energy Progress agreeing to delay collection of financing costs on the construction work in progress for the L.V. Sutton (Sutton) combined cycle facility for one year. The agreement is based upon a return on equity of 10.2 percent and an equity component of the capital structure of 53 percent. The settlement agreement (i) allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, (ii) a $20 million contribution to agencies that provide energy assistance to low-income customers, and (iii) a reduction in the regulatory liability for costs of removal of $20 million for the first year. New rates went into effect on June 1, 2013.

On July 1, 2013, the NCAG appealed the NCUC's approval of the rate of return and capital structure included in the agreement. The NCSC recently docketed the appeal. Legal briefs are due in the fourth quarter of 2013. Duke Energy Progress cannot predict the outcome of this matter.

L.V. Sutton Combined Cycle Facility

Duke Energy Progress is constructing a 625 MW combined cycle natural gas-fired generating facility at its existing Sutton Steam Station in New Hanover County, North Carolina. Total final project cost including AFUDC is estimated to be $570 million. The Sutton project is approximately 94 percent complete and expected to be in service in the fourth quarter of 2013.

Shearon Harris Nuclear Station Expansion

On February 19, 2008, Duke Energy Progress applied to the NRC for a COL for two Westinghouse Electric AP1000 reactors at Harris. On May 2, 2013, Duke Energy Progress requested the NRC to suspend its review activities associated with the COL. As a result of the decision to suspend the COL applications, Duke Energy Progress recorded a pretax impairment charge of $22 million during the second quarter of 2013. This charge represents costs associated with the COL, which are not probable of recovery. On September 16, 2013, the NCUC approved the deferral of the North Carolina retail portion of the remaining COL costs. Approximately $47 million is recorded in Regulatory assets on Duke Energy Progress' Condensed Consolidated Balance Sheet at September 30, 2013.

Wholesale Depreciation Rates

On April 19, 2013, Duke Energy Progress filed an application with FERC for acceptance of changes to generation depreciation rates and in August filed for acceptance of additional changes. These changes will affect the rates of DEP wholesale power customers which purchase or will purchase power under formula rates. Certain Duke Energy Progress wholesale customers filed interventions and protests. FERC accepted the depreciation rate changes, subject to refund, and set the matter for settlement and hearing in a consolidated proceeding. FERC further initiated a section 206 action with respect to the justness and reasonableness of the proposed rate changes. The parties are engaged in settlement discussions. Duke Energy Progress cannot predict the outcome of this matter.

Duke Energy Florida

FPSC Settlement Agreements

On February 22, 2012, the FPSC approved a settlement agreement (the 2012 Settlement) among Duke Energy Florida, the Florida Office of Public Counsel (OPC) and other customer advocates. The 2012 Settlement was to continue through the last billing cycle of December 2016. The agreement addressed four principal matters: (i) the Crystal River Unit 3 delamination prudence review then pending before the FPSC, (ii) certain customer rate matters, (iii) Duke Energy Florida's proposed Levy cost recovery, and (iv) cost of removal reserve.

On October 17, 2013, the FPSC approved a settlement agreement (the 2013 Settlement) between Duke Energy Florida, OPC, and other customer advocates. The 2013 Settlement replaces and supplants the 2012 Settlement and substantially resolves additional issues, including (i) matters related to Crystal River Unit 3, (ii) Levy, (iii) Crystal River 1 and 2 coal units, and (iv) future generation needs in Florida.

Refer to the remaining sections below for further discussion of these settlement agreements.

Crystal River Unit 3

In September 2009, Crystal River Unit 3 began an outage for normal refueling and maintenance as well as an uprate project to increase its generating capability and to replace two steam generators. During preparations to replace the steam generators, workers discovered a delamination, or separation, within the concrete at the periphery of the containment building, which resulted in an extension of the outage. The concrete delamination was caused by redistribution of stresses in the containment wall that occurred when an opening was created to accommodate the replacement of the unit's steam generators. In March 2011, work to return the plant to service was suspended after monitoring equipment identified a new delamination. The second delamination occurred in a different section of the outer wall after repair work was completed and during the late stages of retensioning the containment building. Crystal River Unit 3 remained out of service while Duke Energy Florida conducted an engineering analysis and review of the second delamination and evaluated possible repair options.

Subsequent to March 2011, monitoring equipment detected additional changes and further damage in the partially tensioned containment building. Duke Energy Florida developed a repair plan which had a preliminary cost estimate of $900 million to $1.3 billion.

On February 5, 2013, following the completion of a comprehensive analysis and an independent review by Zapata Incorporated which estimated repair costs to be between $1.49 billion and $3.43 billion depending on the repair scope selected, Duke Energy Florida announced its intention to retire Crystal River Unit 3. Duke Energy Florida concluded that it did not have a high degree of confidence that repair could be successfully completed and licensed within estimated costs and schedule, and that it was in the best interests of Duke Energy Florida's customers and joint owners, and Duke Energy's investors to retire the unit. On February 20, 2013, Duke Energy Florida filed with the NRC a certification of permanent cessation of power operations and permanent removal of fuel from the reactor vessel. Duke Energy Florida developed initial estimates of the cost to decommission the plant during its analysis of whether to repair or retire Crystal River Unit 3. These initial estimates of the cost to decommission the plant resulted in an estimate in 2011 dollars of $989 million. With the final decision to retire, Duke Energy Florida is working to develop a comprehensive decommissioning plan, which will evaluate various decommissioning options and costs associated with each option. The plan will determine resource needs as well as the scope, schedule and other elements of decommissioning. Duke Energy Florida is evaluating the use of a safe storage (SAFSTOR) option for decommissioning. Generally, SAFSTOR involves placing the facility into a safe storage configuration, requiring limited staffing to monitor plant conditions, until the eventual dismantling and decontamination activities occur, usually in 40 to 60 years. This decommissioning approach is currently utilized at a number of retired domestic nuclear power plants and is one of three generally accepted approaches to decommissioning approved by the NRC. An updated site specific decommissioning study will be filed with the NRC and the FPSC. Additional specifics about the decommissioning plan are being developed. The NRC requires that within two years of permanent cessation of power operations the licensee submit a Post-Shutdown Decommissioning Activities Report, which includes a description of planned decommissioning activities, schedule of significant activities, a site specific cost estimate and an environmental impact assessment. Additionally, Duke Energy Florida is developing several license amendment requests and other submittals to revise staffing, training, maintenance, emergency preparedness and security requirements in light of the permanent removal of fuel from the reactor. Duke Energy Florida anticipates filing these submissions with the NRC over the next two years.

Duke Energy Florida maintains insurance coverage through Nuclear Electric Insurance Limited's (NEIL) accidental property damage program. The NEIL coverage generally does not include property damage to or resulting from the containment structure. However, full limit coverage does apply to decontamination and debris removal if required following an accident to ensure public health and safety or if property damage results from a terrorism event.

Duke Energy Florida worked with NEIL for recovery of applicable repair costs and associated replacement power costs throughout the duration of the Crystal River Unit 3 outage. On April 25, 2013 NEIL paid Duke Energy Florida $530 million related to the Crystal River Unit 3 delaminations. Duke Energy Florida has received a total of $835 million in insurance proceeds from NEIL related to the Crystal River Unit 3 delaminations. Duke Energy Florida recorded a regulatory liability of $490 million upon receipt of the April 2013 NEIL settlement proceeds. This amount is being refunded to retail customers through Duke Energy Florida's fuel clause. Proceeds received from NEIL and the related refunds to retail customers are presented in Operating Activities on Duke Energy Florida's Condensed Statements of Cash Flows.

The 2013 Settlement resolves substantially all remaining issues in the FPSC proceeding related to the review of Duke Energy Florida's decision to retire Crystal River Unit 3, the mediated resolution of insurance claims with NEIL, and the costs spent to repair Crystal River Unit 3 since the decision to retire the unit in February 2013; the uprate project; and the components of the regulatory asset to be recovered in rates beginning in 2017 via a separate base rate component.

As a result of retiring the unit, Duke Energy Florida is required to refund $100 million to retail customers through its fuel clause by the 2012 Settlement (retirement decision refund). Duke Energy Florida recorded a Regulatory liability in the third quarter of 2012 related to these replacement power obligations.

Duke Energy Florida has reclassified all Crystal River Unit 3 investments, including property, plant and equipment, nuclear fuel, inventory, and other assets to a regulatory asset. The 2012 Settlement authorized Duke Energy Florida to defer the retail portion of all Crystal River Unit 3 related costs incurred subsequent to retirement including, but not limited to, operations and maintenance and property tax costs in a regulatory asset. A regulatory liability must also be established to capture the difference between (i) actual incurred operations and maintenance and property tax costs in a given year and, (ii) the amount included in customer rates as established in Duke Energy Florida's most recent fully litigated base rate proceeding, effective 2010. Beginning in February 2013, the retail portion of operations and maintenance costs and property taxes associated with Crystal River Unit 3 are being deferred to a regulatory asset. The 2013 Settlement terminates the regulatory asset and/or liability treatment for operation and maintenance and property tax expenses incurred after December 31, 2013.

Duke Energy Florida agreed to forego recovery of $295 million of Crystal River Unit 3 regulatory assets in accordance with the 2013 settlement agreement. This excludes amounts related to the uprate project. Duke Energy Florida recorded a $295 million pretax charge in the second quarter of 2013 for this matter. This amount is included in Impairment charges on Duke Energy Florida's Condensed Statements of Operations and Comprehensive Income.

Duke Energy Florida is allowed to accelerate cash recovery of approximately $135 million of the Crystal River Unit 3 regulatory assets from retail customers from 2014 through 2016 through its fuel clause. Duke Energy Florida will begin recovery of the remaining Crystal River Unit 3 regulatory asset, up to a cap of $1,466 million from retail customers upon the earlier of (i) full recovery of the uncollected Levy investment or (ii) the first billing period of January 2017. Recovery will continue 240 months from inception of collection of the regulatory asset in base rates. The Crystal River Unit 3 base rate component will be adjusted at least every four years. Included in this recovery, but not subject to the cap, are costs of building a dry cask storage facility for spent nuclear fuel, if needed. The return rate will be based on the currently approved AFUDC rate with a return on equity of 7.35 percent, or 70 percent of the currently approved 10.5 percent. The return rate is subject to change if the return on equity changes in the future. Construction of the dry cask storage facility is subject to separate FPSC approval. The regulatory asset associated with the uprate project will continue to be recovered through the Nuclear Cost Recovery Clause (NCRC) over an estimated seven year period beginning in 2013.

Through September 30, 2013, Duke Energy Florida deferred $1,186 million for rate recovery related to Crystal River Unit 3, which is subject to the rate recovery cap in the 2013 settlement. In addition, Duke Energy Florida deferred $324 million for recovery costs associated with building a dry cask storage facility and the original uprate project which is not subject to the rate recovery cap discussed above. Duke Energy Florida does not expect the Crystal River Unit 3 regulatory asset to exceed the cap prior to full cash recovery from its retail customers.

The following table includes a summary of retail customer refunds agreed to in the 2012 Settlement and the 2013 Settlement

30-Sep-13

Remaining Amount to be Refunded

(in millions)

Total

Refunded to date

2013

2014

2015

2016

2012 Settlement refund^(a)

288

139

Retirement decision refund

100

―

NEIL proceeds

490

245

164

―

Total customer refunds

878

342

113

303

Accelerated regulatory asset recovery

-135

―

-38

-59

Net customer refunds

743

342

113

265

(a)

See discussion under Customer Rate Matters section below.

Duke Energy Florida is a party to a master participation agreement and other related agreements with the joint owners of Crystal River Unit 3 which convey certain rights and obligations on Duke Energy Florida and the joint owners. In December 2012, Duke Energy Florida reached an agreement with one group of joint owners related to all Crystal River Unit 3 matters, and is engaged in settlement discussions with the other major group of joint owners regarding resolution of matters associated with Crystal River Unit 3. Duke Energy Florida cannot predict the outcome of this matter.

Customer Rate Matters

Pursuant to the 2013 Settlement, Duke Energy Florida will maintain base rates at the current level through the last billing period of 2018, subject to the return on equity range of 9.5 percent to 11.5 percent. Duke Energy Florida is not required to file a depreciation study, fossil dismantlement study or nuclear decommissioning study until the earlier of the next rate case filing or March 31, 2019. The 2012 Settlement provided for a $150 million increase in base revenue effective with the first billing cycle of January 2013. Costs associated with Crystal River Unit 3 investments were removed from retail rate base effective with the first billing cycle of January 2013. Duke Energy Florida is accruing, for future rate-setting purposes, a carrying charge on the Crystal River Unit 3 investment until the Crystal River Unit 3 regulatory asset is recovered in base rates beginning with the earlier of the full recovery of the Levy investment or the first billing cycle of January 2017. If Duke Energy Florida's retail base rate earnings fall below the return on equity range, as reported on a FPSC-adjusted or pro-forma basis on a Duke Energy Florida monthly earnings surveillance report, Duke Energy Florida may petition the FPSC to amend its base rates during the term of the 2013 Settlement.

In addition to the refunds related to Crystal River Unit 3 mentioned above, Duke Energy Florida is refunding $288 million to retail customers through its fuel clause, as required by the 2012 Settlement.

If Duke Energy Florida determines additional amounts are necessary to fund the Crystal River Unit 3 decommissioning trust, it is permitted to petition for collection of those funds up to $8 million through a base rate surcharge. If the FPSC approves annual decommissioning funding prior to the end of 2018 greater than $8 million, the excess shall be deferred with a carrying cost and recovered through the Capacity Cost Recovery Clause beginning in January 2019.

Levy Nuclear Station

On July 28, 2008, Duke Energy Florida applied to the NRC for a COL for two Westinghouse AP1000 reactors at Levy. Various parties filed a joint petition to intervene in the Levy COL application. On March 26, 2013, the Atomic Safety and Licensing Board issued a ruling that the NRC had carried its burden of demonstrating its Final Environmental Impact Statement complies with the National Environmental Policy Act and applicable NRC regulatory requirements. A mandatory hearing conducted by the five NRC Commissioners is expected to occur in January 2015.

In 2008, the FPSC granted Duke Energy Florida's petition for an affirmative Determination of Need and related orders requesting cost recovery under Florida's nuclear cost-recovery rule, together with the associated facilities, including transmission lines and substation facilities.

Under the terms of the 2012 Settlement, Duke Energy Florida began retail cost-recovery of Levy costs effective in the first billing cycle of January 2013 at the fixed rates contained in the settlement and continuing for a five-year period, with true-up of any actual costs not recovered during the five-year period occurring in the final year. This amount is intended to recover the estimated retail project costs to date plus costs necessary to obtain the COL and any engineering, procurement and construction (EPC) agreement cancellation costs. The 2012 Settlement provided that Duke Energy Florida will treat the allocated wholesale cost of Levy as a retail regulatory asset and include this asset as a component of rate base and amortization expense for regulatory reporting.

Duke Energy Florida updated its retail cost-recovery for Levy effective in the first billing cycle of January 2013 to the fixed rates contained in the 2012 Settlement. These recovery rates continue for a five-year period, with true-up of any actual costs not recovered during the five-year period occurring in the final year. This amount is intended to recover the estimated retail project costs to date plus costs necessary to obtain the COL and any engineering, procurement and construction (EPC) agreement cancellation costs. The consumer parties agree to not oppose Duke Energy Florida continuing to pursue a COL for Levy.

Pursuant to the 2013 Settlement, Duke Energy Florida agrees to terminate the EPC at the earliest reasonable and prudent time. Duke Energy Florida is allowed to recover EPC cancellation costs from its retail customers. Duke Energy Florida will exercise its best efforts to obtain the COL from the NRC prior to March 31, 2015. If Duke Energy Florida, at its own discretion, decides not to pursue the COL prior to March 31, 2015, it agrees to credit customers $10 million as a reduction to fuel costs.

In accordance with the 2013 Settlement, Duke Energy Florida ceased amortization of the wholesale allocation of Levy investments against retail rates. In the second quarter of 2013, Duke Energy Florida recorded a pretax charge of $65 million to write-off the wholesale portion of Levy investments. This amount is included in Impairment charges on Duke Energy Florida's Condensed Statements of Operations and Comprehensive Income.

Recovery of the remaining retail portion of the project costs will occur over five years from 2013 through 2017. Duke Energy Florida has an ongoing responsibility to demonstrate prudency related to the wind down of the Levy investment and the potential for salvage of Levy assets. As of September 30, 2013, Duke Energy Florida has a net uncollected investment in Levy of approximately $265 million, including AFUDC. Of this amount, $118 million is included in Regulatory assets, $117 million related to land and the COL is included in Net, property, plant and equipment, and $30 million is included in Other within Current Assets on Duke Energy Florida's Condensed Balance Sheets.

Crystal River 1 and 2 Coal Units

Duke Energy Florida is evaluating Crystal River 1 and 2 coal units for retirement in order to comply with certain environmental regulations. If those units are retired Duke Energy Florida will continue recovery of existing annual depreciation expense through the end of 2020. Beginning in 2021, Duke Energy Florida will be allowed to recover any remaining net book value of the assets from retail customers through the Capacity Cost Recovery Clause.

New Generation

Duke Energy Florida currently projects a significant need for additional generation to offset the impact of the lost capacity resulting from retirement of Crystal River Unit 3 as well as possible retirement of Crystal River 1 and 2 coal units. The 2013 Settlement establishes a recovery mechanism for additional generation needs. This recovery mechanism, the Generation Base Rate Adjustment (GBRA), will apply to (i) the construction, uprate of existing generation, and/or purchase of up to 1,150 MW of combustion turbine and/or combined cycle generating capacity prior to the end of 2017, and (ii) the construction of additional generation of up to 1,800 MW to be placed in service in 2018 upon FPSC approval of a need determination. The GBRA allows recovery of prudent costs of these items through an increase in base rates, upon the in-service date of such assets, without a general rate case at a 10.5 percent return on equity. On October 8, 2013, Duke Energy Florida issued a request for proposals to evaluate alternatives for an additional generation facility.

Cost of Removal Reserve

The 2012 Settlement and the 2013 Settlement provide Duke Energy Florida the discretion to reduce cost of removal amortization expense up to the balance in the cost of removal reserve until the earlier of its applicable cost of removal reserve reaches zero or the expiration of the 2013 Settlement. Duke Energy Florida may not reduce amortization expense if the reduction would cause it to exceed the appropriate high point of the return on equity range. Duke Energy Florida recognized a $22 million reduction of amortization expense and a $60 million reduction in amortization expense for the three months ended September 30, 2013 and 2012, respectively. Duke Energy Florida recognized a reduction in amortization expense of $95 million and $118 million for the nine months ended September 30, 2013 and 2012, respectively. Duke Energy Florida had eligible cost of removal reserves of $19 million remaining at September 30, 2013, which is impacted by accruals in accordance with its latest depreciation study, removal costs expended, jurisdictional allocation changes and reductions in amortization expense.

Duke Energy Ohio

Capacity Rider Filing

On August 29, 2012, Duke Energy Ohio applied to the PUCO for the establishment of a charge for capacity provided pursuant to its obligations as a Fixed Resource Requirement (FRR) entity. The charge, which is consistent with Ohio's state compensation mechanism, is estimated to be approximately $729 million, and reflects Duke Energy Ohio's embedded cost of capacity. Hearings concluded in May 2013. Duke Energy Ohio expects an order by the end of 2013.

2012 Electric Rate Case

On May 1, 2013, the PUCO approved a settlement agreement (the Electric Settlement) related to Duke Energy Ohio's electric distribution rate case. All intervening parties signed the Electric Settlement. The Electric Settlement provides for a net increase in electric distribution revenues of $49 million, or an average increase of 2.9 percent, based upon a return on equity of 9.84 percent. Revised rates were effective in May 2013.

2012 Natural Gas Rate Case

On April 2, 2013, Duke Energy Ohio, the PUCO Staff, and intervening parties filed a settlement (the Gas Settlement) with the PUCO related to a gas distribution case. The Gas Settlement provides for no increase in base rates for gas distribution service. The Gas Settlement left unresolved the recovery of environmental remediation costs associated with former manufactured gas plants (MGP). The Gas Settlement is based upon a return on equity of 9.84 percent.

Duke Energy Ohio's original application requested MGP remediation costs be recovered through base rates; however, the Gas Settlement establishes a rider for recovery of allowable costs subject to the result of additional litigation. Duke Energy Ohio has requested recovery of approximately $63 million for MGP remediation costs deferred, including carrying costs, through December 31, 2012. Hearings for the MGP litigation were completed in May 2013. Duke Energy Ohio expects an order by the end of 2013.

Regional Transmission Organization Realignment

Duke Energy Ohio, which includes its wholly owned subsidiary Duke Energy Kentucky, transferred control of its transmission assets to effect a Regional Transmission Organization (RTO) realignment from Midcontinent Independent System Operator, Inc. (MISO) to PJM Interconnection, LLC (PJM), effective December 31, 2011.

On December 16, 2010, the FERC issued an order related to MISO's cost allocation methodology surrounding Multi-Value Projects (MVP), a type of MISO Transmission Expansion Planning (MTEP) project cost. MISO expects MVP will fund costs of large transmission projects designed to bring renewable generation from the upper Midwest to load centers in the eastern portion of the MISO footprint. MISO approved MVP proposals with estimated capital project costs of approximately $5.5 billion prior to the date of Duke Energy Ohio's exit from MISO on December 31, 2011. These projects are expected to be undertaken by the constructing transmission owners from 2012 through 2020. The project costs, including an authorized rate of return and associated operating and maintenance expenses will be recovered through MISO over the useful life of the projects. Duke Energy Ohio has historically represented approximately five percent of the MISO system. In 2011, MISO estimated Duke Energy Ohio's MVP obligation to be $514 million based on the future revenue requirements of the proposed MVP projects using an 8.2% discount rate. This estimate could change significantly and is dependent in large part on which projects are actually constructed, the final costs to complete and operate the projects, and the discount rate used to measure the liability, if the liability can be discounted when recorded.

On October 21, 2011, the FERC issued an order on rehearing in this matter largely affirming its original MVP order and conditionally accepting MISO's compliance filing as well as determining the MVP allocation methodology is consistent with cost causation principles and FERC precedent. The order further stated MISO's tariff withdrawal language establishes that once cost responsibility for transmission upgrades is determined, withdrawing transmission owners retain any costs incurred prior to their withdrawal date. In order to preserve its rights, Duke Energy Ohio appealed the FERC order in the D.C. Circuit Court of Appeals. The case was consolidated with appeals of the FERC order by other parties in the Seventh Circuit Court of Appeals. On June 7, 2013, the Seventh Circuit dismissed Duke Energy Ohio's appeal for lack of a final administrative decision on the matter.

On December 29, 2011, MISO filed a Schedule 39 to its tariff with the FERC. Schedule 39 provides for allocation of MVP costs to a withdrawing owner based on the owner's actual transmission load after the owner's withdrawal from MISO, or, if the owner fails to report such load, based on the owner's historical usage in MISO assuming annual load growth. On January 19, 2012, Duke Energy Ohio protested the allocation of MVP costs with the FERC. On February 27, 2012, the FERC accepted Schedule 39 as a just and reasonable basis for MISO to charge MVP costs to a transmission owner that withdraws from MISO after January 1, 2012. The FERC set for hearing (i) whether MISO's proposal to use the methodology in Schedule 39 to calculate the obligation of transmission owners who withdrew from MISO prior to January 1, 2012 is consistent with MVP-related withdrawal obligations in the tariff at the time they withdrew from MISO, and, (ii) if not, what amount of, and methodology for calculating, any MVP cost responsibility should be.

On March 28, 2012, Duke Energy Ohio requested rehearing of FERC's order on MISO's Schedule 39. The Schedule 39 hearing was held in April 2013. A FERC Administrative Law Judge (ALJ) presided over the hearing and issued an initial decision on July 16, 2013. The ALJ ruled Schedule 39 is consistent with MVP-related withdrawal obligations in the tariff at the time Duke Energy Ohio withdrew from MISO and is otherwise just and reasonable. Under this initial decision, Duke Energy Ohio would be liable for MVP costs. Duke Energy Ohio filed exceptions to the initial decision, requesting the FERC overturn the ALJ's decision. After reviewing the initial decision, along with all exceptions and responses to exceptions filed by the parties, the FERC will issue a final decision. Duke Energy Ohio fully intends to appeal to the federal court of appeals if the FERC affirms the ALJ's decision.

On December 22, 2010, the KPSC approved Duke Energy Kentucky's request to effect the RTO realignment, subject to several conditions. Conditions of the approval include a commitment not to seek double-recovery in a future rate case of the transmission expansion fees that may be charged by MISO and PJM in the same period or overlapping periods.

On May 25, 2011 the PUCO approved a settlement between Duke Energy Ohio, Ohio Energy Group, The Office of Ohio Consumers' Counsel and the PUCO Staff related to Duke Energy Ohio's recovery of certain costs of the RTO realignment via a non-bypassable rider. Duke Energy Ohio is allowed to recover all MTEP costs, including but not limited to MVP costs, directly or indirectly charged to Duke Energy Ohio retail customers. Duke Energy Ohio will not seek to recover any portion of the MISO exit obligation, PJM integration fees, or internal costs associated with the RTO realignment, and the first $121 million of PJM transmission expansion costs from Ohio retail customers. Duke Energy Ohio also agreed to vigorously defend against any charges for MVP projects from MISO. After Duke Energy Kentucky made the requested commitments, on January 25, 2011, the KPSC ruled that the approval is no longer conditional.

Upon its exit from MISO on December 31, 2011, Duke Energy Ohio recorded a liability for its exit obligation and share of MTEP costs, excluding MVP. This liability was recorded within Other in Current liabilities and Other in Deferred credits and other liabilities on Duke Energy Ohio's Condensed Consolidated Balance Sheets. In addition to these liabilities, Duke Energy Ohio may also be responsible for costs associated with MISO MVP projects. Duke Energy Ohio is contesting its obligation to pay for such costs. However, depending on the outcome of this matter, Duke Energy Ohio could incur material costs associated with MVP projects, which are not reasonably estimable at this time.

Duke Energy Ohio cannot predict the outcome of these proceedings.

The following table provides a reconciliation of the beginning and ending balance of Duke Energy Ohio's recorded obligations related to its withdrawal from MISO.

(in millions)

Balance at December 31, 2012

Provision / Adjustments

Cash Reductions

Balance at September 30, 2013^(a)

Duke Energy Ohio

-3

(a)

As of September 30, 2013, $70 million is recorded as a Regulatory asset on Duke Energy Ohio's Condensed Consolidated Balance Sheets.

Duke Energy Indiana

Edwardsport IGCC Plant

On November 20, 2007, the IURC granted Duke Energy Indiana a Certificate of Public Convenience and Necessity (CPCN) for the construction of a 618 MW IGCC power plant at Duke Energy Indiana's existing Edwardsport Generating Station in Knox County, Indiana with a cost estimate of $1.985 billion assuming timely recovery of financing costs related to the project. On January 25, 2008, Duke Energy Indiana received the final air permit from the Indiana Department of Environmental Management. The Citizens Action Coalition of Indiana, Inc. (CAC), Sierra Club, Inc. (Sierra Club), Save the Valley, Inc. (Save the Valley), and Valley Watch, Inc. (Valley Watch), all intervenors in the CPCN proceeding (collectively, the Joint Intervenors), appealed the air permit. A settlement related to the air permit was reached on August 30, 2013. The air permit was not impacted by the provisions of the settlement.

Duke Energy Indiana experienced design modifications, quantity increases and scope growth above what was anticipated from the preliminary engineering design, which increased capital costs for the project. In January 2009, the IURC approved a new cost estimate for $2.35 billion (including $125 million of AFUDC). In April 2010, Duke Energy Indiana requested approval of a revised cost estimate of $2.88 billion (including $160 million of AFUDC). In June 2011, Duke Energy Indiana updated its cost forecast to $2.82 billion (excluding AFUDC). In October 2011, Duke Energy Indiana revised its project cost estimate to $2.98 billion (excluding AFUDC). In October 2012, Duke Energy Indiana further revised its projected cost estimate to $3.15 billion (excluding AFUDC).

On December 27, 2012, the IURC approved a settlement agreement related to the cost increase for the construction of the project including subdockets before the IURC related to the project. The Office of Utility Consumer Counselor (OUCC), the Duke Energy Indiana Industrial Group and Nucor Steel-Indiana were parties to the settlement. This settlement agreement resolved all then pending regulatory issues related to the project. The settlement agreement, as approved, capped costs to be reflected in customer rates at $2.595 billion, including estimated AFUDC through June 30, 2012. Duke Energy Indiana is allowed to recover AFUDC after June 30, 2012, until customer rates are revised, with such recovery decreasing to 85 percent on AFUDC accrued after November 30, 2012. Duke Energy Indiana also agreed not to request a retail electric base rate increase prior to March 2013, with rates in effect no earlier than April 1, 2014.

The IURC modified the settlement agreement as previously agreed to by the parties to (i) require Duke Energy Indiana to credit customers for cost control incentive payments the IURC found to be unwarranted as a result of delays that arose from project cost overruns and (ii) provide that if Duke Energy Indiana should recover more than the project costs absorbed by Duke Energy's shareholders through litigation, any surplus must be returned to the Duke Energy Indiana's ratepayers.

Over the course of construction of the project, Duke Energy Indiana recorded pre-tax charges of approximately $897 million, related to the Edwardsport project including the settlement agreement discussed above. Of this amount, pre-tax impairment and other charges of $600 million were recorded during the nine months ended September 30, 2012. These charges were recorded in Impairment charges and Operations, maintenance and other on Duke Energy Indiana's Condensed Consolidated Statements of Operations and Comprehensive Income.

The Joint Intervenors appealed the IURC order approving the April 2012 settlement agreement and other related regulatory orders to the Indiana Court of Appeals. A final decision is anticipated mid-2014.

The project was placed in commercial operation in June 2013.

The costs for the Edwardsport IGCC plant are recovered from retail electric customers via a tracking mechanism, the IGCC Rider. Duke Energy Indiana files information related to the IGCC Rider every six months. In these proceedings, Duke Energy Indiana requests recovery associated with the capped construction costs of the project and operating expenses for the period after the plant is in service. In September 2013, the IURC approved the tenth semi-annual IGCC rider. The eleventh semi-annual IGCC rider proceeding is pending with an order expected by April 2014.

Phase 2 Environmental Compliance Proceeding

On April 10, 2013, the IURC approved Duke Energy Indiana's plan for the addition of certain environmental pollution control projects on several of its coal-fired generating units to comply with existing and proposed environmental rules and regulations. The expenditures approved in the plan will be presented for recovery in Duke Energy Indiana's semi-annual environmental cost recovery rider. The plan calls for a combination of selective catalytic reduction systems, dry sorbent injection systems for SO3 mitigation, activated carbon injection systems and/or mercury re-emission chemical injection systems. The capital costs are estimated at $395 million (excluding AFUDC).

OTHER REGULATORY MATTERS

Progress Energy Merger FERC Mitigation

In June 2012, the FERC approved the merger with Progress Energy, including Duke Energy and Progress Energy's revised market power mitigation plan, the Joint Dispatch Agreement (JDA) and the joint Open Access Transmission Tariff (OATT). The revised market power mitigation plan provides for the acceleration of one transmission project and the completion of seven other transmission projects (Long-term FERC Mitigation) and interim firm power sale agreements during the completion of the transmission projects (Interim FERC Mitigation). The Long-term FERC Mitigation is expected to increase power imported into the Duke Energy Carolinas and Duke Energy Progress service areas and enhance competitive power supply options in the service areas. These projects are expected to be completed no later than 2015.

On July 10, 2012, certain intervenors requested a rehearing seeking to overturn the June 2012 order by the FERC. On August 8, 2012, FERC granted rehearing for further consideration.

Following the closing of the merger, Duke Energy's outside counsel reviewed Duke Energy's mitigation plan and discovered a technical error in the calculations. Duke Energy reported the error to the appropriate regulatory bodies and is working to determine whether additional mitigation measures are necessary. Duke Energy cannot predict the outcome of this matter.

Planned and Potential Coal Plant Retirements

The Subsidiary Registrants periodically file Integrated Resource Plans (IRP) with their state regulatory commissions. The IRPs provide a view of forecasted energy needs over a 10-20 year period, and options being considered to meet those needs. The IRP's filed by the Subsidiary Registrants in 2013, 2012 and 2011 included planning assumptions to potentially retire certain coal-fired generating facilities in North Carolina, South Carolina, Florida, Indiana and Ohio by 2015. The facilities do not have the requisite emission control equipment, primarily to meet Environmental Protection Agency (EPA) regulations that are not yet effective.

The table below contains the net carrying value of generating facilities planned for early retirement or being evaluated for potential retirement included in Property, plant and equipment, net on the Condensed Consolidated Balance Sheets. In addition to the amounts presented below, Duke Energy Carolinas, Duke Energy Progress and Duke Energy Indiana have $71 million, $187 million and $57 million, respectively, of net carrying value related to previously retired coal generation facilities included in Regulatory assets on their Condensed Consolidated Balance Sheets.

30-Sep-13

Duke Energy

Duke Energy Carolinas

^(b)

Progress Energy

Duke Energy Progress

^(c)(d)

Duke Energy Florida

^(e)

Duke Energy Ohio

^(f)

Duke Energy Indiana

^(g)

Capacity (in MW)

3,244

200

1,448

575

873

928

668

Remaining net book value (in millions)^(a)

319

171

112

124

(a)

Included in Property, plant and equipment, net as of September 30, 2013, on the Condensed Consolidated Balance Sheets, unless otherwise noted.

(b)

Includes Lee Units 1 and 2. Excludes 170 MW Lee Unit 3 that is expected to be converted to gas in 2014. Duke Energy Carolinas expects to retire or convert these units by December 2020 in conjunction with a settlement agreement associated with the Cliffside Unit 6 air permit.

(c)

Includes Sutton Station, which is expected to be retired by the end of 2013.

(d)

Remaining net book value of Duke Energy Progress' Sutton Station is included in Generation facilities to be retired, net, on the Condensed Consolidated Balance Sheets at September 30, 2013.

(e)

Includes Crystal River Units 1 and 2.

(f)

Includes Beckjord Station Units 2 through 6 and Miami Fort Unit 6. Beckjord units have no remaining book value. Beckjord units 2 and 3 were retired effective October 1, 2013.

(g)

Includes Wabash River Units 2 through 6. Wabash River Unit 6 is being evaluated for potential conversion to gas. Duke Energy Indiana committed to retire or convert these units by June 2018 in conjunction with a settlement agreement associated with the Edwardsport air permit.

Duke Energy continues to evaluate the potential need to retire these coal-fired generating facilities earlier than the current estimated useful lives, and plans to seek regulatory recovery for amounts that would not be otherwise recovered when any of these assets are retired. However, such recovery, including recovery of carrying costs on remaining book values, could be subject to future regulatory approvals and therefore cannot be assured.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2013
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	5. COMMITMENTS AND CONTINGENCIES
	ENVIRONMENTAL
	Duke Energy is subject to international, federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal, and other environmental matters. The Subsidiary Registrants are subject to federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These regulations can be changed from time to time, imposing new obligations on the Duke Energy Registrants.
	The following environmental matters impact all of the Duke Energy Registrants.
	Remediation Activities
	The Duke Energy Registrants are responsible for environmental remediation at various contaminated sites. These include some properties that are part of ongoing operations and sites formerly owned or used by Duke Energy entities. These sites are in various stages of investigation, remediation, and monitoring. Managed in conjunction with relevant federal, state, and local agencies, activities vary with site conditions and locations, remediation requirements, complexity, and sharing of responsibility. If remediation activities involve joint and several liability provisions, strict liability, or cost recovery or contribution actions, the Duke Energy Registrants could potentially be held responsible for contamination caused by other parties. The Duke Energy Registrants may share liability associated with contamination with other potentially responsible parties, and may also benefit from insurance policies or contractual indemnities that cover some or all cleanup costs. The Duke Energy Registrants continually assess the nature and extent of known or potential environmental contingencies. Liabilities are recorded when losses become probable and are reasonably estimable. The Duke Energy Registrants have accrued costs associated with remediation activities at some of their current and former sites for the stages of investigation, remediation, and monitoring that can be reasonably estimated, as well as other relevant environmental contingent liabilities. The Duke Energy Registrants cannot estimate the total costs that may be incurred in connection with the remediation at all stages of all sites because the extent of environmental impact, allocation among potentially responsible parties, remediation alternatives, and/or regulatory decisions have not yet been determined. Additional costs associated with remediation activities at certain sites are likely to be incurred in the future. These additional costs could be significant. Costs associated with remediation activities within the Duke Energy Registrants' operations are typically expensed as Operation, maintenance and other in the Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.
	The following table contains information regarding reserves for probable and estimable costs related to the Duke Energy Registrants' various environmental sites. These amounts are recorded in Other within Deferred Credits and Other Liabilities on the Duke Energy Registrants' Condensed Consolidated Balance Sheets.

	(in millions)		Duke Energy			Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Balance at December 31, 2011		$	61		$	12	$	23	$	11	$	12	$	28	$	9
	Provisions / adjustments			43			1		16		4		12		10		2
	Cash reductions			-19			―		-7		-2		-5		-15		-2
	Balance at September 30, 2012		$	85		$	13	$	32	$	13	$	19	$	23	$	9


	Balance at December 31, 2012		$	75		$	12	$	33	$	14	$	19	$	15	$	8
	Provisions / adjustments			6			―		5		1		4		-1		1
	Cash reductions			-17			―		-6		-2		-4		-8		-2
	Balance at September 30, 2013		$	64		$	12	$	32	$	13	$	19	$	6	$	7

	The PUCO has approved Duke Energy Ohio's deferral of the costs incurred for probable and estimable costs related to the MGP environmental sites. Duke Energy Ohio is seeking recovery of those costs in its natural gas distribution rate case as discussed in Note 4.
	Additional losses in excess of recorded reserves the Duke Energy Registrants' could incur for the stages of investigation, remediation, and monitoring for their environmental sites that can be reasonably estimated at this time are presented in the table below.

	(in millions)
	Duke Energy					$	75
	Duke Energy Carolinas						29
	Progress Energy						6
	Duke Energy Progress						3
	Duke Energy Florida						3
	Duke Energy Ohio						35
	Duke Energy Indiana						5

	Clean Water Act 316(b)
	The EPA proposed a cooling water intake structures rule on April 20, 2011. The proposed rule advances one main approach and three alternatives. The main approach establishes aquatic protection requirements for existing facilities that withdraw 2 million gallons or more of water per day from U.S. water sources for cooling purposes. Based on the main approach proposed, most, if not all of the steam electric generating facilities the Duke Energy Registrants own are likely affected sources unless retired prior to implementation of the 316(b) requirements.
	The deadline for issuance of the final 316(b) rule is November 2013. If the rule is finalized as proposed, modifications to the intakes could be required as early as mid- to-late 2017. The Duke Energy Registrants are unable to predict the outcome of this rulemaking.
	Cross-State Air Pollution Rule (CSAPR)
	On August 8, 2011, the final Cross-State Air Pollution Rule (CSAPR) was published in the Federal Register. The CSAPR established state-level annual sulfur dioxide (SO2) budgets and annual seasonal nitrogen oxide (NOx) budgets that were to take effect on January 1, 2012.
	On August 21, 2012, the D.C. Circuit Court vacated the CSAPR. The court also directed the EPA to continue administering the Clean Air Interstate Rule (CAIR). The Duke Energy Registrants have been complying with the CAIR since 2009. The CAIR requires additional reductions in SO2 and NOx emissions beginning in 2015. On June 24, 2013, the U.S. Supreme Court (Supreme Court) granted the EPA's petitions for a writ of certiorari. Oral arguments will be heard on December 10, 2013. The Supreme Court is likely to issue its decision on the merits by mid-2014.
	The Duke Energy Registrants cannot predict the outcome of the proceedings. Continued compliance with the CAIR pending the outcome of the rehearing process will not result in the Duke Energy Registrants adding new emission controls.
	Coal Combustion Residuals (CCR)
	On June 21, 2010, the EPA proposed a regulation under the Resource Conservation and Recovery Act, related to coal combustion residuals (CCR). CCR is a term the EPA uses to describe the coal combustion byproducts associated with the generation of electricity. The EPA proposal contains two regulatory options whereby CCRs not employed in approved beneficial use applications would either (i) be regulated as hazardous waste or (ii) continue to be regulated as non-hazardous waste.
	On October 29, 2013, the U.S. District Court for the District of Columbia ordered the EPA to complete the timeline for CCR rulemaking within 60 days. The Duke Energy Registrants cannot predict the outcome of this rulemaking, but the impact could be significant.
	Steam Electric Effluent Limitation Guidelines
	On June 7, 2013, the EPA proposed Steam Electric Effluent Limitations Guidelines (ELGs). The EPA is under a court order to complete a final rule by May 22, 2014. The EPA has proposed eight options for the rule, which vary in stringency and cost. The proposed regulation applies to seven waste streams, including wastewater from air pollution control equipment and ash transport water. Most, if not all of the steam electric generating facilities the Duke Energy Registrants own are likely affected sources. Compliance is proposed as soon as possible after July 1, 2017, but may extend until July 1, 2022. The Duke Energy Registrants are unable to predict the outcome of the rulemaking, but the impact could be significant.
	Greenhouse Gas New Source Performance Standards (NSPS)
	On September 20, 2013, the EPA proposed a rule to establish carbon dioxide (CO2) emissions standards for new pulverized coal, IGCC, and natural gas combined cycle electric generating units commencing construction on or after the date the proposal appears in the Federal Register. Any future coal and IGCC units will be required to employ carbon capture and storage technology to meet the proposed CO2 emission standard.

	The Duke Energy Registrants do not expect a material impact on their future results of operations or cash flows based on the EPA's proposal. The final rule, however, could be significantly different from the proposal. It is not known when the EPA might finalize the rule.
	On June 25, 2013, the President of the United States issued a memorandum directing the EPA to propose CO2 emissions requirements for existing fossil-fueled electric generating units by June 1, 2014, and to finalize the guidelines for states to develop their own regulations for implementing the guidelines by June 1, 2015. The memorandum directed the EPA to require states to submit their implementation regulations for approval by June 30, 2016.
	The Duke Energy Registrants are unable to predict the outcome of this rulemaking.
	Mercury and Air Toxics Standards (MATS)
	The final Mercury and Air Toxics Standards rule, previously referred to as the Utility MACT Rule, was issued on February 16, 2012. The final rule establishes emission limits for hazardous air pollutants from new and existing coal-fired and oil-fired steam electric generating units. The rule requires sources to comply with emission limits by April 16, 2015. Under the Clean Air Act (CAA), permitting authorities have the discretion to grant up to a one-year compliance extension, on a case-by-case basis, to sources that are unable to complete the installation of emission controls before the compliance deadline. The Duke Energy Registrants continue to develop and implement strategies for complying with the rule. Strategies to achieve compliance with the final rule will include installing new air emission control equipment, developing monitoring processes, fuel switching, and accelerating retirement of some coal-fired electric-generating units. For additional information, refer to Note 4 regarding potential plant retirements.
	Numerous petitions for review of the final rule have been filed with the D.C. Circuit Court. Oral arguments have not been scheduled. The Duke Energy Registrants cannot predict the outcome of the litigation or how it might affect their compliance with the MATS requirements.
	Refer to the table below for a summary of estimated costs to comply with the MATS regulations.
	Estimated Cost and Impacts of EPA Rulemakings
	The ultimate compliance requirements for MATS, Clean Water 316(b), CCRs and ELGs will not be known until all the rules have been finalized. However, for planning purposes, the Duke Energy Registrants currently estimate the cost of new control equipment that may need to be installed on existing power plants to comply with these EPA regulations could total $5 billion to $6 billion, excluding AFUDC, over the next 10 years. The table below includes estimated costs for new control equipment necessary to comply with the MATS rule, which is the only rule that has been finalized

	(in millions)		Range
	Duke Energy		$	650	-	800
	Duke Energy Carolinas			65	-	85
	Progress Energy			7	-	30
	Duke Energy Progress			5	-	10
	Duke Energy Florida			2	-	20
Duke Energy Ohio			40	-	85
Duke Energy Indiana			540	-	600

The Duke Energy Registrants also expect to incur increased fuel, purchased power, operation and maintenance, and other expenses, and costs for replacement generation for potential coal-fired power plant retirements as a result of these EPA regulations. Until the final regulatory requirements are known and can be fully evaluated, the potential compliance costs associated with these EPA regulatory actions are subject to considerable uncertainty. Therefore, the actual compliance costs incurred may be materially different from these estimates based on the timing and requirements of the final EPA regulations. The Duke Energy Registrants intend to seek regulatory recovery of amounts incurred associated with regulated operations in complying with these regulations. Refer to Note 4 for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.
LITIGATION
Duke Energy
Progress Energy Merger Shareholder Litigation
On May 31, 2013, the Delaware Chancery Court consolidated four shareholder derivative lawsuits filed in 2012. The Court also appointed a lead plaintiff and counsel for plaintiffs and designated the case as In Re Duke Energy Corporation Derivative Litigation. The lawsuit names as defendants James E. Rogers and the ten other members of the Duke Energy board of directors who were also members of the pre-merger Duke Energy board of directors (Legacy Duke Energy Directors). Duke Energy is named as a nominal defendant. The case alleges claims for breach of fiduciary duties of loyalty and care in connection with the post-merger change in CEO. On October 1, 2013, defendants filed a motion to stay the case pending final disposition of the Nieman v. Duke Energy Corporation, et al. case in North Carolina. A decision is pending on the motion to stay.
On August 3, 2012, Duke Energy was served with a shareholder Derivative Complaint, which was transferred to the North Carolina Business Court (Krieger v. Johnson, et al.). The lawsuit names as defendants, William D. Johnson, James E. Rogers and the Legacy Duke Energy Directors. Duke Energy is named as a nominal defendant. The lawsuit alleges claims for breach of fiduciary duty in granting excessive compensation to Mr. Johnson. A decision on a motion to dismiss made by Mr. Rogers and the Legacy Duke Energy Directors remains pending.
Two shareholder Derivative Complaints, filed in 2012 in federal district court in Delaware, were consolidated as Tansey v. Rogers, et al. The case alleges claims for breach of fiduciary duty and waste of corporate assets, as well as claims under Section 14(a) and 20(a) of the Exchange Act. Duke Energy is named as a nominal defendant. On May 17, 2013, the judge granted defendants' motion to stay the litigation until a decision is rendered on the motion to dismiss in the Nieman v. Duke Energy Corporation, et al. case in North Carolina.
Duke Energy, the Legacy Duke Energy Directors and certain Duke Energy officers are also defendants in a purported securities class action lawsuit (Nieman v. Duke Energy Corporation, et al). This lawsuit consolidates three lawsuits originally filed in July 2012, and is pending in the United States District Court for the Western District of North Carolina. The plaintiffs allege federal Securities Act and Exchange Act claims based on allegations of materially false and misleading representations and omissions in the Registration Statement filed on July 7, 2011, and purportedly incorporated into other documents, all in connection with the post-merger change in CEO. The claims are purportedly brought on behalf of a class of all persons who purchased or otherwise acquired Duke Energy securities between June 11, 2012 and July 9, 2012. On July 26, 2013, the Magistrate Judge recommended the District Court Judge deny the defendants' motion to dismiss. On October 2, 2013, the District Judge heard defendants' objections to this recommendation. A decision is pending on the motion to dismiss.
It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with these lawsuits.
Alaskan Global Warming Lawsuit
On February 26, 2008, the governing bodies of an Inupiat village in Alaska, filed suit in the U.S. Federal Court for the Northern District of California against Peabody Coal and various oil and power company defendants, including Duke Energy and certain of its subsidiaries. Plaintiffs brought the action on their own behalf and on behalf of the village's 400 residents. The lawsuit alleges that defendants' emissions of CO2 contributed to global warming and constitute a private and public nuisance. Plaintiffs also allege that certain defendants, including Duke Energy, conspired to mislead the public with respect to global warming. The plaintiffs in the case requested damages in the range of $95 million to $400 million related to the cost of relocating the Village of Kivalina. On May 20, 2013, the plaintiffs' Petition for Certiorari to the Supreme Court was denied, ending the case.
Price Reporting Cases
A total of five lawsuits were filed against Duke Energy affiliates and other energy companies and remain pending in a consolidated, single federal court proceeding in Nevada.
Each of these cases contain similar claims, that defendants' allegedly manipulated natural gas markets by various means, including providing false information to natural gas trade publications and entering into unlawful arrangements and agreements in violation of the antitrust laws of the respective states. Plaintiffs seek damages in unspecified amounts.
On July 19, 2011, the judge granted a defendant's motion for summary judgment in two of the remaining five cases to which Duke Energy affiliates are a party. The Ninth Circuit Court of Appeals subsequently reversed the lower court's decision. On August 26, 2013, the defendants, including Duke Energy, filed a petition for certiorari to the U.S. Supreme Court.
It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with the remaining matters. However, based on Duke Energy's past experiences with similar cases of this nature, it does not believe its exposure under these remaining matters is material.
Crescent Resources Litigation
On September 3, 2010, the Crescent Resources (Crescent) Litigation Trust sued Duke Energy along with various affiliates and several individuals, including current and former employees of Duke Energy, in the U.S. Bankruptcy Court for the Western District of Texas. The case was subsequently transferred to the United States District Court in Austin, Texas. The Crescent Resources Litigation Trust was established in May 2010 pursuant to the plan of reorganization approved in the Crescent bankruptcy proceedings. The complaint alleges in 2006 the defendants caused Crescent to borrow approximately $1.2 billion and immediately thereafter distribute most of the loan proceeds to Crescent's parent company without benefit to Crescent. The complaint further alleges that Crescent was rendered insolvent by the transactions, and that the loan proceeds of $1.2 billion as well as Crescent's interest of $252 million and fee payments to the creditor banks of $15 million are subject to recovery by the Crescent bankruptcy estate as an alleged fraudulent transfer. The plaintiff requests return of the loan proceeds, the payments to the creditor banks and accrued interest from the time of the transfers, as well as other statutory and equitable relief, punitive damages, and attorneys' fees. Duke Energy and its affiliated defendants believe that the referenced 2006 transactions were legitimate and did not violate any state or federal law. The defendants' motion for partial summary judgment to dismiss the plaintiff's claims for return of interest and fees paid by Crescent to the creditor banks was granted in part with respect to the interest payments and denied with respect to the fee payments.
Mediation held August 21-22, 2012 was unsuccessful. Duke Energy and its affiliated defendants tendered a partial settlement offer of $50 million in August 2013. This amount was recorded as Operation, maintenance and other in Duke Energy's Condensed Consolidated Statements of Operations during the second quarter of 2013. On October 4, 2013 the Court granted the defendants' motion for summary judgment on the fraudulent transfer claim. State law claims including breach of fiduciary duty against all of the defendants remain in the case. The parties have scheduled mediation for November 2013. Trial has been set to commence in January 2014.
It is not possible to estimate the maximum exposure to loss that may occur in connection with this lawsuit. The ultimate resolution of this matter could have a material effect on the results of operations, cash flows or financial position of Duke Energy.
Brazil Expansion Lawsuit
On August 9, 2011, the State of São Paulo sued Duke Energy International Geracao Paranapenema S.A. (DEIGP) in Brazilian state court. The lawsuit claims DEIGP is under a continuing obligation to expand installed generation capacity in the State of São Paulo by 15 percent pursuant to a stock purchase agreement under which DEIGP purchased generation assets from the state. On August 10, 2011, a judge granted an ex parte injunction ordering DEIGP to present a detailed expansion plan in satisfaction of the 15 percent obligation. DEIGP has previously taken a position that the 15 percent expansion obligation is no longer viable given changes that have occurred in the electric energy sector since privatization. DEIGP submitted its proposed expansion plan on November 11, 2011, but reserved objections regarding enforceability. No trial date has been set. It is not possible to predict whether Duke Energy will incur any liability or to estimate the damages, if any, it might incur in connection with this matter.

Duke Energy Carolinas
New Source Review (NSR)
In 1999-2000, the U.S. Department of Justice (DOJ) filed a number of complaints and notices of violation against multiple utilities across the country for alleged violations of the NSR provisions of the CAA. The DOJ filed these complaints on behalf of the EPA and joined by various citizen groups and states. Generally, the government alleges projects performed at various coal-fired units were major modifications, as defined in the CAA. By undertaking these projects, the utilities violated the CAA by not obtaining permits or installing the best available emission controls for SO2, NOx and particulate matter. The complaints seek the installation of pollution control technology on various generating units that allegedly violated the CAA, and unspecified civil penalties in amounts of up to $37,500 per day for each violation. A number of plants owned by Duke Energy Carolinas are subject to these allegations. Duke Energy Carolinas asserts there were no CAA violations because the applicable regulations do not require permitting in cases where the projects undertaken are “routine” or otherwise do not result in a net increase in emissions.
In 2000, the government sued Duke Energy Carolinas in the U.S. District Court in Greensboro, North Carolina. The EPA claims 29 projects performed at 25 of Duke Energy Carolinas' coal-fired units violate these NSR provisions. Three environmental groups intervened in the case. In August 2003, the trial court issued a summary judgment adopting Duke Energy Carolinas' positions on the standard to be used for measuring an increase in emissions, and granted judgment in favor of Duke Energy Carolinas. On April 2, 2007, the trial court's decision was reversed and remanded for trial by the Supreme Court. Duke Energy Carolinas continues to assert the projects were routine or not projected to increase emissions. The parties filed a stipulation in which the United States and the plaintiff-intervenors have dismissed with prejudice 16 claims. In exchange, Duke Energy Carolinas dismissed certain affirmative defenses. The parties filed motions for summary judgment on the remaining claims. On November 6, 2013, the court issued an order denying Duke Energy Carolinas' motion for summary judgment. Duke Energy Carolinas has requested leave to file another motion for summary judgment on alternative grounds. That motion for leave, as well as the Plaintiff's motion for summary judgment, remain pending.
It is not possible to predict whether Duke Energy Carolinas will incur any liability or to estimate the damages, if any, it might incur in connection with this matter. Ultimate resolution of these matters could have a material effect on the results of operations, cash flows or financial position of Duke Energy Carolinas. However, the appropriate regulatory treatment will be pursued for any costs incurred in connection with such resolution.
Asbestos-related Injuries and Damages Claims
Duke Energy Carolinas has experienced numerous claims for indemnification and medical cost reimbursement related to Asbestos exposure. These claims relate to damages for bodily injuries alleged to have arisen from exposure to or use of asbestos in connection with construction and maintenance activities conducted on its electric generation plants prior to 1985. As of September 30, 2013, there were 157 asserted claims for non-malignant cases with the cumulative relief sought of up to $30 million, and 35 asserted claims for malignant cases with the cumulative relief sought of up to $11 million. Based on Duke Energy Carolinas' experience, it is expected that the ultimate resolution of most of these claims likely will be less than the amount claimed.
Asbestos-related reserves totaled $633 million at September 30, 2013 and $751 million at December 31, 2012. These amounts are classified in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities on Duke Energy Carolinas' Condensed Consolidated Balance Sheets. These reserves are based upon the minimum amount in Duke Energy Carolinas' best estimate of the range of loss for current and future asbestos claims through 2033. Duke Energy Carolinas believes that it is possible there will be additional claims filed after 2033. In light of uncertainties inherent in a longer-term forecast, Duke Energy Carolinas cannot reasonably estimate the indemnity and medical costs that might be incurred after 2033 related to such potential claims. Asbestos-related loss estimates incorporate anticipated inflation, if applicable, and are recorded on an undiscounted basis. These reserves are based upon current estimates and are subject to greater uncertainty as the projection period lengthens. A significant upward or downward trend in the number of claims filed, the nature of the alleged injury, and the average cost of resolving each such claim could change the estimated liability, as could any substantial or favorable verdict at trial. A federal legislative solution, further state tort reform or structured settlement transactions could also change the estimated liability. Given the uncertainties associated with projecting matters into the future and numerous other factors outside its control, it is possible Duke Energy Carolinas may incur asbestos liabilities in excess of the recorded reserves.
Duke Energy Carolinas has third-party insurance to cover certain losses related to asbestos-related injuries and damages above an aggregate self-insured retention of $476 million. Duke Energy Carolinas' cumulative payments began to exceed the self-insurance retention in 2008. Future payments up to the policy limit will be reimbursed by the third party insurance carrier. The insurance policy limit for potential future insurance recoveries indemnification and medical cost claim payments is $897 million in excess of the self-insured retention. Receivables for insurance recoveries were $649 million related to this policy at September 30, 2013 and $781 million at December 31, 2012. These amounts are classified in Other within Investments and Other Assets and Receivables on Duke Energy Carolinas' Condensed Consolidated Balance Sheets. Duke Energy Carolinas is not aware of any uncertainties regarding the legal sufficiency of insurance claims. Duke Energy Carolinas believes the insurance recovery asset is probable of recovery as the insurance carrier continues to have a strong financial strength rating.
Progress Energy
Synthetic Fuels Matters
Progress Energy and a number of its subsidiaries and affiliates are defendants in a lawsuit arising out of an Asset Purchase Agreement dated as of October 19, 1999, and amended as of August 23, 2000 (the Asset Purchase Agreement). Parties to the Asset Purchase Agreement include U.S. Global, LLC (Global); Earthco synthetic fuels facilities (Earthco); certain affiliates of Earthco; EFC Synfuel LLC (which was owned indirectly by Progress Energy) and certain of its affiliates (collectively, the Progress Affiliates). In a case filed in the Circuit Court for Broward County, Florida, in March 2003 (the Florida Global Case), Global requested an unspecified amount of compensatory damages, as well as declaratory relief. Global asserted (i) it was entitled to an interest in two synthetic fuels facilities previously owned by the Progress Affiliates and an option to purchase additional interests in the two synthetic fuels facilities and (ii) it was entitled to damages because the Progress Affiliates prohibited it from procuring purchasers for the synthetic fuels facilities. As a result of the 2007 expiration of the Internal Revenue Code Section 29 tax credit program, all of Progress Energy's synthetic fuels businesses were abandoned and the synthetic fuels businesses were reclassified as discontinued operations.
In November 2009, the court ruled in favor of Global. In December 2009, Progress Energy made a $154 million payment, which represented payment of the total judgment, including prejudgment interest, and a required premium equivalent to two years of interest, to the Broward County Clerk of Court bond account. Progress Energy continued to accrue interest related to this judgment.
On October 3, 2012, the Florida Fourth District Court of Appeals reversed the lower court ruling. The court held that Global was entitled to approximately $90 million of the amount paid into the registry of the court. Progress Energy was entitled to a refund of the remainder of the funds. Progress Energy received cash and recorded a $63 million pre-tax gain for the refund in December 2012. The gain was recorded in Income from Discontinued Operations, net of tax in the Consolidated Statements of Operations.
On May 9, 2013, Global filed a Seventh Amended Complaint asserting a single count for breach of the Asset Purchase Agreement and seeking specific performance. A trial is scheduled to commence in January 2014.
In a second suit filed in the Superior Court for Wake County, N.C., Progress Synfuel Holdings, Inc. et al. v. U.S. Global, LLC (the North Carolina Global Case), the Progress Affiliates seek declaratory relief consistent with their interpretation of the Asset Purchase Agreement. In August 2003, the Wake County Superior Court stayed the North Carolina Global Case, pending the outcome of the Florida Global Case. Based upon the verdict in the Florida Global Case, Progress Energy anticipates dismissal of the North Carolina Global Case.
Duke Energy Progress and Duke Energy Florida
Spent Nuclear Fuel Matters
The Nuclear Waste Policy Act of 1982 (as amended) (NWPA) provides the framework of interim storage and permanent disposal facilities for high-level radioactive waste materials for development by the federal government. The U.S. Department of Energy (DOE) is responsible for the selection and construction of a facility for the permanent disposal of spent nuclear fuel and high-level radioactive waste. Pursuant to the NWPA, Duke Energy Progress and Duke Energy Florida entered into contracts with the DOE for disposal of spent nuclear fuel by no later than January 31, 1998. All similarly situated utilities were required to sign the same Standard Contract for Disposal of Spent Nuclear Fuel. The DOE failed to begin taking spent nuclear fuel by January 31, 1998.
On December 12, 2011, Duke Energy Progress and Duke Energy Florida sued the United States in the U.S. Court of Federal Claims. The lawsuit claims the DOE breached the standard contract and asserts damages incurred from January 1, 2006 through December 31, 2010. Claims for all periods prior to 2006 have been resolved. Duke Energy Progress and Duke Energy Florida assert damages of $84 million and $21 million, respectively, for the period January 1, 2006 through December 31, 2010. The trial occurred September 23-25, 2013. A decision is expected in the fourth quarter 2014. Duke Energy Progress and Duke Energy Florida may file subsequent damage claims as they incur additional costs. Duke Energy Progress and Duke Energy Florida cannot predict the outcome of this matter.

Duke Energy Ohio
Antitrust Lawsuit
In January 2008, four plaintiffs, including individual, industrial and nonprofit customers, filed a lawsuit against Duke Energy Ohio in federal court in the Southern District of Ohio. Plaintiffs alleged Duke Energy Ohio conspired to provide inequitable and unfair price advantages for certain large business consumers. The lawsuit alleges this was done by entering into non-public option agreements with large business consumers in exchange for their withdrawal of challenges to Duke Energy Ohio's pending Rate Stabilization Plan (RSP). The RSP was implemented in early 2005. On March 31, 2009, the District Court granted Duke Energy Ohio's motion to dismiss. On June 4, 2012, the Sixth Circuit Court of Appeals reversed the district court's decision and remanded the matter on all claims for trial on the merits. Mediations held in December 2012 and March 2013 were unsuccessful. A ruling is pending on the plaintiffs' motion to certify this matter as a class action. It is not possible to predict whether Duke Energy Ohio will incur any liability or to estimate the damages, if any, which may be incurred in connection with this lawsuit.
Asbestos-related Injuries and Damages Claims
Duke Energy Ohio has been named as a defendant or co-defendant in lawsuits related to asbestos exposure at its electric generating stations. The impact on Duke Energy Ohio's results of operations, cash flows or financial position of these cases to date has not been material. Based on estimates under varying assumptions concerning uncertainties, such as, among others: (i) the number of contractors potentially exposed to asbestos during construction or maintenance of Duke Energy Ohio generating plants, (ii) the possible incidence of various illnesses among exposed workers, and (iii) the potential settlement costs without federal or other legislation that addresses asbestos tort actions, Duke Energy Ohio estimates that the range of reasonably possible exposure in existing and future suits over the foreseeable future is not material. This estimated range of exposure may change as additional settlements occur and claims are made and more case law is established.
Duke Energy Indiana
Edwardsport IGCC
On December 11, 2012, Duke Energy Indiana filed an arbitration action against General Electric Company and Bechtel Corporation in connection with their work at the Edwardsport IGCC facility. Duke Energy Indiana is seeking damages of not less than $560 million. An arbitration hearing is scheduled for October 2014. Duke Energy Indiana cannot predict the outcome of this matter.
Other Litigation and Legal Proceedings
The Duke Energy Registrants are involved in other legal, tax and regulatory proceedings arising in the ordinary course of business, some of which involve substantial amounts. The Duke Energy Registrants believe the final disposition of these proceedings will not have a material effect on their results of operations, cash flows or financial position.
The Duke Energy Registrants expense legal costs related to the defense of loss contingencies as incurred.
The Duke Energy Registrants have exposure to certain legal matters as described above. The Duke Energy Registrants have recorded reserves for these proceedings and exposures as presented in the table below. These reserves represent management's best estimate of probable loss as defined in the accounting guidance for contingencies. The amount for Duke Energy includes the reserve related to the Crescent Resources Litigation, which is discussed above. The estimated reasonably possible range of loss for all other non-asbestos related matters in excess of the recorded reserves is not material. Duke Energy Carolinas has insurance coverage for certain of these losses incurred as presented in the table below.

(in millions)		30-Sep-13			31-Dec-12
Reserves for Legal and Other Matters^(a)
Duke Energy^(b)		$	782		$	846
Duke Energy Carolinas^(b)			633			751
Progress Energy			74			79
Duke Energy Progress			10			12
Duke Energy Florida^(c)			43			47
Duke Energy Indiana			8			8
Probable Insurance Recoveries^(d)
Duke Energy^(e)		$	649		$	781
Duke Energy Carolinas^(e)			649			781

(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
(b)	Includes reserves for asbestos-related injuries and damages claims.
(c)	Includes workers' compensation claims.
(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

OTHER COMMITMENTS AND CONTINGENCIES
General
As part of their normal business, the Duke Energy Registrants are party to various financial guarantees, performance guarantees, and other contractual commitments to extend guarantees of credit and other assistance to various subsidiaries, investees, and other third parties. These guarantees involve elements of performance and credit risk, which are not included on their respective Condensed Consolidated Balance Sheets. The possibility of any of the Duke Energy Registrants having to honor their contingencies is largely dependent upon future operations of various subsidiaries, investees, and other third parties, or the occurrence of certain future events.
In addition, the Duke Energy Registrants enter into various fixed-price, non-cancelable commitments to purchase or sell power, take-or-pay arrangements, transportation, or throughput agreements and other contracts that may or may not be recognized on their respective Condensed Consolidated Balance Sheets. Some of these arrangements may be recognized at fair value on their respective Condensed Consolidated Balance Sheets if such contracts meet the definition of a derivative and the normal purchase/normal sale (NPNS) exception does not apply. In most cases, the Duke Energy Registrants' purchase obligation contracts contain provisions for price adjustments, minimum purchase levels, and other financial commitments.

Debt_and_Credit_Facilities

Debt and Credit Facilities	9 Months Ended
Debt and Credit Facilities	Sep. 30, 2013
Debt And Credit Facilities [Abstract]	'
Debt And Credit Facilities	'
	6. DEBT AND CREDIT FACILITIES
	SUMMARY OF SIGNIFICANT DEBT ISSUANCES
	The following table summarizes the Duke Energy Registrants' significant debt issuances since December 31, 2012 (in millions).

	Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana			Duke Energy
	Unsecured Debt
	January 2013^(a)		Jan-73	5.125	%		$	500		$	―		$	―		$	―		$	500
	June 2013^(b)		Jun-18	2.1	%			500			―			―			―			500
	August 2013^(c)(d)		Aug-23	11	%			―			―			―			―			220
	October 2013^(e)		Oct-23	3.95	%			400			―			―			―			400
	Secured Debt
	February 2013^(f)(g)		Dec-30	2.043	%			―			―			―			―			203
	February 2013^(f)		Jun-37	4.74	%			―			―			―			―			220
	April 2013^(h)		Apr-26	5.456	%			―			―			―			―			230
	First Mortgage Bonds
	March 2013⁽ⁱ⁾		Mar-43	4.1	%			―			500			―			―			500
	June 2013^(j)		Jun-41	4	%			―			48			―			―			48
	July 2013^(k)		Jul-43	4.9	%			―			―			―			350			350
	July 2013^(k)(l)		Jul-16	0.619	%			―			―			―			150			150
	September 2013^(m)		Sep-23	3.8	%			―			―			300			―			300
	September 2013^(m)(n)		Mar-15	0.4	%			―			―			150			―			150
	Total issuances						$	1,400		$	548		$	450		$	500		$	3,771

	(a)	Callable after January 2018 at par. Proceeds from the issuance were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS). The securities were redeemed at par plus accrued and unpaid distributions, payable upon presentation on the redemption date. The remaining net proceeds were used to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 11 for additional information about the QUIPS.
	(b)	Proceeds from the issuance were used to repay $250 million of current maturities. The remaining net proceeds were used for general corporate purposes, including the repayment of outstanding commercial paper.
	(c)	Proceeds from the issuance were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.
	(d)	The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.
	(e)	Proceeds from the issuance were used to repay commercial paper as well as for general corporate purposes.
	(f)	Represents the conversion of construction loans related to a renewable energy project issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.
	(g)	The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.
	(h)	Represents primarily the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.
	(i)	Proceeds from the issuance were used to repay notes payable to affiliated companies as well as for general corporate purposes.
	(j)	Callable after June 2023 at par. Proceeds from the issuance were used to redeem $48 million of First Mortgage Bonds with a higher interest rate.
	(k)	Proceeds from the issuances were used to repay $400 million of current maturities.
	(l)	The debt is floating rate based on 3-month London Interbank Offered Rate (LIBOR) and a fixed spread of 35 basis points.
	(m)	Proceeds from the issuances were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.
	(n)	The debt is floating rate based on 3-month LIBOR plus a fixed spread of 14 basis points.

	CURRENT MATURITIES OF LONG-TERM DEBT
	The following table shows the significant components of Current maturities of long-term debt on the Duke Energy Registrants' respective Condensed Consolidated Balance Sheets. The Duke Energy Registrants currently anticipate satisfying these obligations with a combination of cash, future cash from operations and additional commercial paper and long-term borrowings.

	(in millions)		Maturity Date	Interest Rate			30-Sep-13
	Unsecured Debt
	Duke Energy (Parent)		Feb-14	6.3	%		$	750
	Progress Energy (Parent)		Mar-14	6.05	%			300
	Duke Energy (Parent)		Sep-14	3.95	%			500
	First Mortgage Bonds
	Duke Energy Carolinas		Nov-13	5.75	%			400
	Other							357
	Current maturities of long-term debt						$	2,307

	AVAILABLE CREDIT FACILITIES
	Duke Energy has a five-year master credit facility. The credit facility has a capacity of $6 billion through November 2017. The Duke Energy Registrants each have borrowing capacity under the master credit facility up to specified sublimits for each borrower. Duke Energy has the unilateral ability at any time to increase or decrease the borrowing sublimits of each borrower, subject to a maximum sublimit for each borrower. See the table below for the current borrowing sublimits for each of the borrowers as of September 30, 2013. The amount available under the master credit facility has been reduced to backstop issuances of commercial paper, certain letters of credit and variable-rate demand tax-exempt bonds that may be put to the Duke Energy Registrants at the option of the holder. Borrowing sublimits for the Subsidiary Registrants are also reduced for certain amounts outstanding under the money pool arrangement.

			30-Sep-13
	(in millions)		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Duke Energy
	Facility size^(a)		$	1,750		$	1,250		$	750		$	750		$	750		$	750		$	6,000
	Reduction to backstop issuances
	Notes payable and commercial paper^(b)			-256			-300			-244			―			-29			-150			-979
	Outstanding letters of credit			-57			-4			-2			-1			―			―			-64
	Tax-exempt bonds			―			-75			―			―			-84			-81			-240
	Available capacity		$	1,437		$	871		$	504		$	749		$	637		$	519		$	4,717

(a)	Represents the sublimit of each borrower at September 30, 2013.
(b)	Duke Energy issued $450 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas and Duke Energy Indiana. The balances are classified as long-term borrowings within Long-term Debt in Duke Energy Carolina’s and Duke Energy Indiana’s Condensed Consolidated Balance Sheets.


		30-Sep-13
(in millions)		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Duke Energy
Facility size^(a)		$	1,750		$	1,250		$	750		$	750		$	750		$	750		$	6,000
Reduction to backstop issuances
Notes payable and commercial paper^(b)			-256			-300			-244			―			-29			-150			-979
Outstanding letters of credit			-57			-4			-2			-1			―			―			-64
Tax-exempt bonds			―			-75			―			―			-84			-81			-240
Available capacity		$	1,437		$	871		$	504		$	749		$	637		$	519		$	4,717

(a)	Represents the sublimit of each borrower at September 30, 2013.
(b)	Duke Energy issued $450 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas and Duke Energy Indiana. The balances are classified as long-term borrowings within Long-term Debt in Duke Energy Carolina’s and Duke Energy Indiana’s Condensed Consolidated Balance Sheets.


(in millions)		Maturity Date	Interest Rate			30-Sep-13
Unsecured Debt
Duke Energy (Parent)		Feb-14	6.3	%		$	750
Progress Energy (Parent)		Mar-14	6.05	%			300
Duke Energy (Parent)		Sep-14	3.95	%			500
First Mortgage Bonds
Duke Energy Carolinas		Nov-13	5.75	%			400
Other							357
Current maturities of long-term debt						$	2,307


Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana			Duke Energy
Unsecured Debt
January 2013^(a)		Jan-73	5.125	%		$	500		$	―		$	―		$	―		$	500
June 2013^(b)		Jun-18	2.1	%			500			―			―			―			500
August 2013^(c)(d)		Aug-23	11	%			―			―			―			―			220
October 2013^(e)		Oct-23	3.95	%			400			―			―			―			400
Secured Debt
February 2013^(f)(g)		Dec-30	2.043	%			―			―			―			―			203
February 2013^(f)		Jun-37	4.74	%			―			―			―			―			220
April 2013^(h)		Apr-26	5.456	%			―			―			―			―			230
First Mortgage Bonds
March 2013⁽ⁱ⁾		Mar-43	4.1	%			―			500			―			―			500
June 2013^(j)		Jun-41	4	%			―			48			―			―			48
July 2013^(k)		Jul-43	4.9	%			―			―			―			350			350
July 2013^(k)(l)		Jul-16	0.619	%			―			―			―			150			150
September 2013^(m)		Sep-23	3.8	%			―			―			300			―			300
September 2013^(m)(n)		Mar-15	0.4	%			―			―			150			―			150
Total issuances						$	1,400		$	548		$	450		$	500		$	3,771

(a)	Callable after January 2018 at par. Proceeds from the issuance were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS). The securities were redeemed at par plus accrued and unpaid distributions, payable upon presentation on the redemption date. The remaining net proceeds were used to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 11 for additional information about the QUIPS.
(b)	Proceeds from the issuance were used to repay $250 million of current maturities. The remaining net proceeds were used for general corporate purposes, including the repayment of outstanding commercial paper.
(c)	Proceeds from the issuance were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.
(d)	The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.
(e)	Proceeds from the issuance were used to repay commercial paper as well as for general corporate purposes.
(f)	Represents the conversion of construction loans related to a renewable energy project issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.
(g)	The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.
(h)	Represents primarily the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.
(i)	Proceeds from the issuance were used to repay notes payable to affiliated companies as well as for general corporate purposes.
(j)	Callable after June 2023 at par. Proceeds from the issuance were used to redeem $48 million of First Mortgage Bonds with a higher interest rate.
(k)	Proceeds from the issuances were used to repay $400 million of current maturities.
(l)	The debt is floating rate based on 3-month London Interbank Offered Rate (LIBOR) and a fixed spread of 35 basis points.
(m)	Proceeds from the issuances were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.
(n)	The debt is floating rate based on 3-month LIBOR plus a fixed spread of 14 basis points.

Goodwill_Intangible_Assets_Imp

Goodwill, Intangible Assets & Impairments	9 Months Ended
Goodwill, Intangible Assets & Impairments	Sep. 30, 2013
Goodwill [Abstract]	'
Goodwill	'
	7. GOODWILL
	The following tables present goodwill by reportable operating segment for Duke Energy and Duke Energy Ohio.

	Duke Energy

	(in millions)		USFE&G		Commercial Power		International Energy		Total
	Balance at December 31, 2012
	Goodwill		$	15,950	$	933	$	353	$	17,236
	Accumulated impairment charges			―		-871		―		-871
	Balance at December 31, 2012, as adjusted for accumulated impairment charges			15,950		62		353		16,365
	Acquisitions ^(a)			2		2		-5		-1
	Foreign exchange and other changes			-2		―		-17		-19
	Balance at September 30, 2013
	Goodwill			15,950		935		331		17,216
	Accumulated impairment charges			―		-871		―		-871
	Balance at September 30, 2013, as adjusted for accumulated impairment charges		$	15,950	$	64	$	331	$	16,345

	(a)	Amounts represent purchase price adjustments related to the Progress Energy merger at USFE&G, a minor renewables acquisition at Commercial Power and the Chilean hydro acquisition at International Energy. See Note 2 for further information on purchase price adjustments related to the Progress Energy Merger.

	Duke Energy Ohio

	(in millions)		Franchised Electric & Gas		Commercial Power		Total
	Balance at December 31, 2012
	Goodwill		$	1,137	$	1,188	$	2,325
	Accumulated impairment charges			-216		-1,188		-1,404
	Balance at December 31, 2012, as adjusted for accumulated impairment charges			921		―		921
	Foreign exchange and other changes			-1		―		-1
	Balance at September 30, 2013
	Goodwill			1,136		1,188		2,324
	Accumulated impairment charges			-216		-1,188		-1,404
	Balance at September 30, 2013, as adjusted for accumulated impairment charges		$	920	$	―	$	920

	Progress Energy
	Progress Energy had Goodwill of $3,655 million within the Franchised Electric operating segment as of September 30, 2013 and December 31, 2012, for which there were no accumulated impairment charges.
	Impairment Testing
	Duke Energy, Progress Energy, and Duke Energy Ohio are required to perform an annual goodwill impairment test as of the same date each year and, accordingly, perform their annual impairment testing of goodwill as of August 31. Duke Energy, Progress Energy, and Duke Energy Ohio update their test between annual tests if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value. As the fair value of Duke Energy, Progress Energy, and Duke Energy Ohio's reporting units exceeded their respective carrying values at the date of the annual impairment analysis, Duke Energy, Progress Energy, and Duke Energy Ohio did not record any impairment charges in the third quarter of 2013.

Risk_Management_Derivative_Ins

Risk Management, Derivative Instruments and Hedging Activities	9 Months Ended
	Sep. 30, 2013
Risk Management, Derivative Instruments And Hedging Activities [Abstract]	'
Risk Management, Derivative Instruments And Hedging Activities	'
	8. RISK MANAGEMENT, DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
	The Duke Energy Registrants closely monitor risks associated with commodity price and interest rates changes on their operations. The Duke Energy Registrants use various commodity and interest rate instruments to manage these risks. Certain of these derivative instruments qualify for hedge accounting and are designated as hedging instruments. Other instruments either do not qualify for hedge accounting or have not been designated as hedges (hereinafter referred to as undesignated contracts). The Duke Energy Registrants' primary use of energy commodity derivatives is to hedge their generation portfolio against exposure to changes in the prices of electricity and fuel. Interest rate swaps are entered into to manage interest rate risk primarily associated with the Duke Energy Registrants' borrowings. Additionally, Duke Energy Carolinas', Duke Energy Progress' and Duke Energy Florida's nuclear decommissioning trust fund (NDTF) investment holdings may include certain derivative instruments, such as interest rate swaps and credit default swaps, as part of their overall investment strategies. The fair value of these derivative instruments are included within Nuclear decommissioning trust funds on the Condensed Consolidated Balance Sheets and are not material to the investment balances at September 30, 2013 and December 31, 2012. The remaining disclosures in this footnote do not reflect any derivatives included in the NDTFs as they are not material to the information presented.
	Accounting guidance requires the recognition of all derivative instruments not identified as NPNS as either assets or liabilities at fair value in the Condensed Consolidated Balance Sheets. For derivative instruments that qualify for hedge accounting, the Duke Energy Registrants may elect to designate such derivatives as either cash flow hedges or fair value hedges. The Duke Energy Registrants offset fair value amounts recognized on the Condensed Consolidated Balance Sheets related to derivative instruments executed with the same counterparty under the same master netting agreement.
	Within the Duke Energy Registrants' regulated businesses, gains and losses on all derivative contracts are reflected as regulatory liabilities or assets and not as a component of AOCI or current period income. As a result, changes in fair value of these derivatives have no immediate earnings impact.
	Within the Duke Energy Registrants' unregulated businesses, for derivative instruments that qualify for hedge accounting and are designated as cash flow hedges, the effective portion of gains or losses are reported as a component of AOCI. Amounts are subsequently reclassified from AOCI to earnings in the same period or periods during which the hedged transaction affects earnings. Any gains or losses on the derivative that represent either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in current earnings. For derivative instruments that qualify and are designated as fair value hedges, gains or losses on the derivative and the fully or partially offsetting losses or gains on the hedged item are recognized in earnings in the current period. The Duke Energy Registrants include gains or losses on the derivative in the same line item as offsetting losses or gains on the hedged item in the Condensed Consolidated Statements of Operations. Additionally, the Duke Energy Registrants enter into derivative agreements that are economic hedges that either do not qualify for hedge accounting or have not been designated as hedges. The changes in fair value of these undesignated derivative instruments are reflected in current earnings.
	COMMODITY PRICE RISK
	The Duke Energy Registrants are exposed to the impact of changes in future prices of electricity (energy, capacity, and financial transmission rights), coal, and natural gas as a result of their operations. With respect to commodity price risks associated with electricity generation, the Duke Energy Registrants are exposed to changes including, but not limited to, the cost of the coal and natural gas used to generate electricity, the price of electricity sold in wholesale markets, and the cost of energy, capacity and financial transmission rights purchased for resale in wholesale markets. Exposure to commodity price risk is influenced by a number of factors, including, but not limited to, the term of contracts, the liquidity of markets, and delivery locations.
	Commodity Fair Value Hedges
	At September 30, 2013, no open commodity derivative instruments were designated as fair value hedges.
	Commodity Cash Flow Hedges
	At September 30, 2013, no material open commodity derivative instruments were designated as cash flow hedges.
	Undesignated Contracts
	The Duke Energy Registrants use derivative contracts as economic hedges to manage market risk exposures that arise from providing electricity generation and capacity to large energy customers, energy aggregators, retail customers, and other wholesale companies. Undesignated contracts may include contracts not designated as a hedge, contracts that do not qualify for hedge accounting, derivatives that do not or no longer qualify for the NPNS scope exception, and de-designated hedge contracts. These contracts expire as late as 2017.
	Undesignated contracts also include contracts associated with operations that Duke Energy continues to wind down or has included as discontinued operations. As these undesignated contracts expire as late as 2021, Duke Energy has entered into economic hedges that leave it minimally exposed to price changes over the duration of these contracts.
	Duke Energy Carolinas and Duke Energy Progress use derivative contracts as economic hedges to manage market risk exposures that arise from electricity generation. Duke Energy Carolinas and Duke Energy Progress have also entered into firm power sale agreements, which are accounted for as derivative instruments, as part of the Interim FERC Mitigation in connection with Duke Energy's merger with Progress Energy. Duke Energy Carolinas' undesignated contracts as of September 30, 2013, are primarily associated with forward sales and purchases of electricity.
	Duke Energy Florida uses derivative contracts primarily as economic hedges to manage market risk exposures that arise from electricity generation. Undesignated contracts at September 30, 2013, are primarily associated with forward purchases of natural gas.
	Duke Energy Ohio uses derivative contracts as economic hedges to manage market risk exposures that arise from providing electricity generation and capacity to large energy customers, energy aggregators, retail customers, and other wholesale companies. Undesignated contracts at September 30, 2013, are primarily associated with forward sales and purchases of power, coal, and natural gas.
	Duke Energy Indiana uses derivative contracts as economic hedges to manage market risk exposures that arise from electricity generation. Undesignated contracts at September 30, 2013, are primarily associated with forward purchases and sales of power and financial transmission rights.
	Volumes
	The tables below show information relating to the volume of the Duke Energy Registrants outstanding commodity derivative contracts. Amounts disclosed represent the notional volumes of commodity contracts accounted for at fair value. For option contracts, notional amounts which represent the notional volumes times the probability of exercising the option based on current price volatility. Volumes associated with contracts qualifying for and designated as NPNS have been excluded from the table below. Amounts disclosed represent the absolute value of notional amounts. The Duke Energy Registrants have netted contractual amounts where offsetting purchase and sale contracts exist with identical delivery locations and times of delivery. Where all commodity positions are perfectly offset, no quantities are shown.

			30-Sep-13
			Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Electricity-energy (Gigawatt-hours)^(a)			63,264		1,305		925		925		―		59,662		702
	Natural gas (millions of decatherms)			536		―		336		129		207		200		―

			31-Dec-12
			Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Electricity-energy (Gigawatt-hours)^(a)			52,104		2,028		1,850		1,850		―		51,215		97
	Natural gas (millions of decatherms)			528		―		348		118		230		180		―

	(a)	Amounts at Duke Energy Ohio include intercompany positions that eliminate at Duke Energy.

	INTEREST RATE RISK
	The Duke Energy Registrants are exposed to changes in interest rates as a result of their issuance or anticipated issuance of variable-rate and fixed-rate debt and commercial paper. Interest rate exposure is managed by limiting variable-rate instruments to a percentage of total debt and by monitoring changes in interest rates. To manage risk associated with changes in interest rates, the Duke Energy Registrants may enter into interest rate swaps, U.S. Treasury lock agreements, and other financial contracts. In anticipation of certain fixed-rate debt issuances, a series of forward starting interest rate swaps may be executed to lock in components of current market interest rates. These instruments are later terminated prior to or upon the issuance of the corresponding debt. When these transactions occur within a business that meets the criteria for regulatory accounting treatment, these contracts may be treated as undesignated and any pretax gain or loss recognized from inception to termination of the hedges would be recorded as a regulatory liability or asset and amortized as a component of interest expense over the life of the debt. In businesses that don't meet the criteria for regulatory accounting treatment, these derivatives may be designated as hedges whereby any pretax gain or loss recognized from inception to termination of the hedges would be recorded in AOCI and amortized as a component of interest expense over the life of the debt.
	Duke Energy has a combination foreign exchange, pay fixed-receive floating interest rate swap to fix the US Dollar equivalent payments on a floating rate Chilean debt issue.
	The following tables show notional amounts for derivatives related to interest rate risk.

				30-Sep-13
	(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
	Cash flow hedges^(a)(b)			$	1,190		$	―		$	―		$	―		$	―
	Undesignated contracts				34			―			―			27			―
	Total notional amount			$	1,224		$	―		$	―		$	27		$	―

				31-Dec-12
	(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
	Cash flow hedges^(a)			$	1,047		$	―		$	―		$	―		$	―
	Undesignated contracts				290			50			50			27			200
	Fair value hedges				250			―			―			250			―
	Total notional amount			$	1,587		$	50		$	50		$	277		$	200

	(a)	Duke Energy includes amounts related to non-recourse variable rate long-term debt of VIEs of $602 million and $620 million at September 30, 2013, and at December 31, 2012, respectively.
	(b)	In October 2013, $375 million of interest rate swaps designated as cash flow hedges at Duke Energy were terminated due to a new debt issuance. See Note 6 for more information.

	DUKE ENERGY
	The fair value amounts of derivative contracts, and the line items in the Condensed Consolidated Balance Sheets on which they were included were as follows. The fair values of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Duke Energy nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Consolidated Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

			30-Sep-13						31-Dec-12
	(in millions)		Asset			Liability			Asset			Liability
	Derivatives Designated as Hedging Instruments
	Commodity contracts
	Current Liabilities: Other		$	―		$	1		$	―		$	2
	Deferred Credits and Other Liabilities: Other			―			―			―			1
Interest rate contracts
Current Assets: Other			―			―			2			―
Investments and Other Assets: Other			21			―			7			―
Current Liabilities: Other			―			52			―			81
Deferred Credits and Other Liabilities: Other			―			14			―			35
Total Derivatives Designated as Hedging Instruments			21			67			9			119
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other			46			1			41			2
Investments and Other Assets: Other			167			104			106			50
Current Liabilities: Other			136			372			106			407
Deferred Credits and Other Liabilities: Other			4			171			2			255
Interest rate contracts
Current Liabilities: Other			―			1			―			76
Deferred Credits and Other Liabilities: Other			―			4			―			8
Total Derivatives Not Designated as Hedging Instruments			353			653			255			798
Total Derivatives		$	374		$	720		$	264		$	917

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Duke Energy's financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements, or with an Independent System Operator (ISO) such as MISO or PJM. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. Duke Energy may also have available accounts receivable or accounts payable that are subject to master netting agreements that would offset exposures in the event of bankruptcy. These amount are not included in the table below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	159		$	175			$	338		$	265
Gross amounts offset			-142			-108				-168			-122
Net amount subject to master netting			17			67				170			143
Amounts not subject to master netting			23			17				89			28
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	40	^(a)	$	84	^(b)		$	259	^(c)	$	171	^(d)

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	127		$	96			$	402		$	295
Gross amounts offset			-114			-54				-151			-90
Net amounts subject to master netting			13			42				251			205
Amounts not subject to master netting			22			19				166			54
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	35	^(a)	$	61	^(b)		$	417	^(c)	$	259	^(d)

(a)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.
(b)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
(c)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.
(d)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

The amounts of gains and losses recognized on derivative instruments designated and qualifying as cash flow hedges by type of derivative contract, and the Condensed Consolidated Statements of Operations line items in which such gains and losses were included when reclassified from AOCI were as follows.

		Three Months Ended September 30,
(in millions)		2013				2012
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts			$	―		$	-4
Commodity contracts				―			1
Total Pretax Gains (Losses) Recorded in AOCI			$	―		$	-3
Location of Pretax Gains (Losses) Reclassified from AOCI into Earnings^(a)
Interest rate contracts^(b)
Interest expense			$	―		$	2
Total Pretax Losses Reclassified from AOCI into Earnings			$	―		$	2


		Nine Months Ended September 30,
(in millions)		2013				2012
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts			$	71		$	-30
Commodity contracts				1			1
Total Pretax Gains (Losses) Recorded in AOCI			$	72		$	-29
Location of Pretax Gains (Losses) Reclassified from AOCI into Earnings^(a)
Interest rate contracts^(b)
Interest expense			$	-2		$	―
Total Pretax Losses Reclassified from AOCI into Earnings			$	-2		$	―

(a)	Represents the gains and losses on cash flow hedges previously recorded in AOCI during the term of the hedging relationship and reclassified into earnings during the current period.
(b)	Amounts in AOCI related to terminated hedges are reclassified to earnings as the interest expense is recorded. The effective portion of the hedges will be amortized to interest expense over the term of the related debt.

There was no hedge ineffectiveness during the three and nine months ended September 30, 2013 and 2012, and no gains or losses were excluded from the assessment of hedge effectiveness during the same periods.
At September 30, 2013 and 2012, $65 million and $136 million, respectively, of pretax deferred net losses on derivative instruments related to interest rate cash flow hedges were included as a component of AOCI. A $1 million pretax loss is expected to be recognized in earnings during the next 12 months as the hedged transactions occur.
The amounts of pretax gains and losses recognized on undesignated contracts by type of derivative instrument, and the line items in the Condensed Consolidated Statements of Operations in which such gains and losses were included or deferred on the Condensed Consolidated Balance Sheets as regulatory assets or liabilities were as follows.

		Three Months Ended September 30,
(in millions)				2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric			$	3		$	-22
Revenue: Nonregulated electric, natural gas and other				-7			-28
Other income and expenses				―			-1
Fuel used in electric generation and purchased power - regulated				-68			-135
Fuel used in electric generation and purchased power - nonregulated				-2			―
Interest rate contracts
Interest expense				-4			-4
Total Pretax Losses Recognized in Earnings			$	-78		$	-190
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets			$	-29		$	61
Regulatory liabilities				6			12
Interest rate contracts
Regulatory assets				12			7
Total Pretax Losses Recognized as Regulatory Assets or Liabilities			$	-11		$	80


		Nine Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric			$	10		$	-22
Revenue: Nonregulated electric, natural gas and other				-15			8
Other income and expenses				―			-1
Fuel used in electric generation and purchased power - regulated^(a)				-157			-135
Fuel used in electric generation and purchased power - nonregulated				-20			―
Interest rate contracts
Interest expense				-13			-4
Total Pretax (Losses) Gains Recognized in Earnings			$	-195		$	-154
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-34		$	61
Regulatory liabilities				10			34
Interest rate contracts^(c)
Regulatory assets				51			-3
Total Pretax Gains Recognized as Regulatory Assets or Liabilities			$	27		$	92

(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
(b)	Amounts are recorded as regulatory assets and liabilities in the Condensed Consolidated Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.
(c)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

DUKE ENERGY CAROLINAS
The fair value amounts of derivative contracts, and the line items in the Condensed Consolidated Balance Sheets on which they were included were as follows. The fair values of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Duke Energy Carolinas nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Consolidated Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

		30-Sep-13						31-Dec-12
(in millions)		Asset			Liability			Asset			Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts^(a)
Current Liabilities: Other		$	―		$	3		$	―		$	6
Deferred Credits and Other Liabilities: Other			―			1			―			6
Total Derivatives Not Designated as Hedging Instruments			―			4			―			12
Total Derivatives		$	―		$	4		$	―		$	12

(a)	Substantially all of these contracts receive regulatory accounting treatment.

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Duke Energy Carolinas' financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. Duke Energy Carolinas may also have available accounts receivable or accounts payable to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Amounts not subject to master netting			―			―				3			1
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―		$	―			$	3	^(a)	$	1	^(b)

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Amounts not subject to master netting			―			―				6			6
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―		$	―			$	6	^(a)	$	6	^(b)

(a)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.
(b)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

Losses on cash flow hedges reclassified at Duke Energy Carolinas for the three and nine months ended September 30, 2013 and 2012 were not material.

For the three and nine months ended September 30, 2013 and 2012, Duke Energy Carolinas had $22 million and $23 million, respectively, of pretax deferred net losses on settled interest rate cash flow hedges remaining in AOCI.
For the three and nine months ended September 30, 2013, pretax losses recognized on undesignated contracts for Duke Energy Carolinas were insignificant. For the three and nine months ended September 30, 2012, pretax losses recognized on undesignated contracts for Duke Energy Carolinas were $13 million.
PROGRESS ENERGY
The fair value amounts of derivative contracts, and the line items in the Condensed Consolidated Balance Sheets on which they were included were as follows. The fair values of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Progress Energy nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Consolidated Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

		30-Sep-13						31-Dec-12
(in millions)		Asset			Liability			Asset			Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current Liabilities: Other		$	―		$	―		$	―		$	2
Deferred Credits and Other Liabilities: Other			―			1			―			1
Total Derivatives Designated as Hedging Instruments			―			1			―			3
Derivatives Not Designated as Hedging Instruments
Commodity contracts^(a)
Current Assets: Other			―			―			3			―
Investments and Other Assets: Other			―			―			8			―
Current Liabilities: Other			1			159			―			231
Deferred Credits and Other Liabilities: Other			2			125			―			195
Interest rate contracts
Current Liabilities: Other			―			―			―			11
Total Derivatives Not Designated as Hedging Instruments			3			284			11			437
Total Derivatives		$	3		$	285		$	11		$	440

(a)	Substantially all of these contracts receive regulatory treatment.

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Progress Energy's financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. Progress Energy may also have available accounts receivable or accounts payables to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	1		$	2			$	159		$	122
Gross amounts offset			-1			-1				-13			-15
Net amount subject to master netting			―			1				146			107
Amounts not subject to master netting			―			―				―			4
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―	^(a)	$	1	^(b)		$	146	^(c)	$	111	^(d)

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	3		$	8			$	244		$	192
Gross amounts offset			―			―				-22			-36
Net amount subject to master netting			3			8				222			156
Amounts not subject to master netting			―			―				―			4
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	3	^(a)	$	8	^(b)		$	222	^(c)	$	160	^(d)

(a)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.
(b)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
(c)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.
(d)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

The amounts of gains and losses recognized on derivative instruments designated and qualifying as cash flow hedges by type of derivative contract, and the Condensed Consolidated Statements of Operations and Comprehensive Income line items in which such gains and losses were included when reclassified from AOCI were as follows.

		Three Months Ended September 30,
(in millions)		2013				2012
Pretax Losses Recorded in AOCI
Commodity contracts				―			1
Total Pretax Losses Recorded in AOCI			$	―		$	1
Location of Pretax Losses Reclassified from AOCI into Earnings^(a)
Interest rate contracts^(b)
Interest expense			$	-5		$	-2
Total Pretax Losses Reclassified from AOCI into Earnings			$	-5		$	-2


		Nine Months Ended September 30,
(in millions)		2013				2012
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts			$	―		$	-11
Commodity contracts				1			1
Total Pretax Gains (Losses) Recorded in AOCI			$	1		$	-10
Location of Pretax Losses Reclassified from AOCI into Earnings^(a)
Interest rate contracts^(b)
Interest expense			$	-5		$	-12
Total Pretax Losses Reclassified from AOCI into Earnings			$	-5		$	-12

(a)	Represents the gains and losses on cash flow hedges previously recorded in AOCI during the term of the hedging relationships and reclassified into earnings during the current period.
(b)	Amounts in AOCI related to terminated hedges are reclassified to earnings as the interest expense is recorded. The effective portion of the hedges will be amortized to interest expense over the term of the related debt.

At September 30, 2013 and 2012, $60 million and $71 million, respectively, of pretax deferred net losses on derivative instruments related to interest rate cash flow hedges were included as a component of AOCI. A $5 million pretax loss is expected to be recognized in earnings during the next 12 months as the hedged transactions occur. Effective with the Duke Energy merger, Progress Energy no longer designates interest rate contracts for regulated operations as cash flow hedges. As a result, pretax losses on open derivative contracts as of the date of the merger were reclassified from AOCI to Regulatory assets.
The amounts of pretax gains and losses recognized on undesignated contracts by type of derivative instrument, and the line items in the Consolidated Statements of Operations and Comprehensive Income in which such gains and losses were included or deferred on the Condensed Consolidated Balance Sheets as regulatory assets or liabilities were as follows.

		Three Months Ended September 30,
(in millions)				2013			2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues			$	3		$	-9
Fuel used in electric generation and purchased power^(a)				-68			-135
Interest rate contracts
Interest expense				-4			-4
Total Pretax Losses Recognized in Earnings			$	-69		$	-148
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-31		$	60
Interest rate contracts^(c)
Regulatory assets				4			2
Total Pretax (Losses) Gains Recognized as Regulatory Assets or Liabilities			$	-27		$	62


		Nine Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues			$	10		$	-9
Fuel used in electric generation and purchased power^(a)				-157			-395
Interest rate contracts
Interest expense				-13			-4
Total Pretax Losses Recognized in Earnings			$	-160		$	-408
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-34		$	-108
Interest rate contracts^(c)
Regulatory assets				13			2
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities			$	-21		$	-106

(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
(b)	Amounts are recorded as regulatory assets and liabilities in the Condensed Consolidated Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.
(c)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

DUKE ENERGY PROGRESS
The fair value amounts of derivative contracts, and the line items in the Condensed Consolidated Balance Sheets on which they were included were as follows. The fair values of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Duke Energy Progress nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Consolidated Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

		30-Sep-13						31-Dec-12
(in millions)		Asset			Liability			Asset			Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current Liabilities: Other		$	―		$	―		$	―		$	1
Deferred Credits and Other Liabilities: Other			―			―			―			1
Total Derivatives Designated as Hedging Instruments			―			―			―			2
Derivatives Not Designated as Hedging Instruments
Commodity contracts^(a)
Current Assets: Other			―			―			1			―
Investments and Other Assets: Other			―			―			1			―
Current Liabilities: Other			―			65			―			85
Deferred Credits and Other Liabilities: Other			1			43			―			68
Interest rate contracts
Current Liabilities: Other			―			―			―			11
Total Derivatives Not Designated as Hedging Instruments			1			108			2			164
Total Derivatives		$	1		$	108		$	2		$	166

(a)	Substantially all of these contracts receive regulatory treatment.

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Duke Energy Progress' financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. Duke Energy Progress may also have available accounts receivable or accounts payable to offset exposures in the events of bankruptcy. These amounts are not included in the tables below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	―		$	1			$	65		$	43
Gross amounts offset			―			―				-3			-2
Net amount subject to master netting			―			1				62			41
Amounts not subject to master netting			―			―				―			―
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―	^(a)	$	1	^(b)		$	62	^(c)	$	41	^(d)

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	1		$	1			$	97		$	69
Gross amounts offset			―			―				-2			-7
Net amount subject to master netting			1			1				95			62
Amounts not subject to master netting			―			―				―			―
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	1	^(a)	$	1	^(b)		$	95	^(c)	$	62	^(d)

(a)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.
(b)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
(c)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.
(d)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

The amounts of gains and losses recognized on derivative instruments designated and qualifying as cash flow hedges by type of derivative contract, and the Condensed Consolidated Statements of Operations and Comprehensive Income line items in which such gains and losses were included when reclassified from AOCI were as follows.

		Nine Months Ended September 30,
(in millions)		2013				2012
Pretax Gains and (Losses) Recorded in AOCI
Interest rate contracts^(b)			$	―		$	-7
Total Pretax Losses Recorded in AOCI			$	―		$	-7
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings^(a)
Interest rate contracts
Interest expense			$	―		$	-5
Total Pretax Losses Reclassified from AOCI into Earnings			$	―		$	-5

(a)	Represents the gains and losses on cash flow hedges previously recorded in AOCI during the term of the hedging relationships and reclassified into earnings during the current period.
(b)	Amounts in AOCI related to terminated hedges are reclassified to earnings as the interest expense is recorded. The effective portion of the hedges will be amortized to interest expense over the term of the related debt.

At September 30, 2012, $1 million of pretax deferred net losses on derivative instruments related to interest rate cash flow hedges were included as a component of AOCI. Effective with the Duke Energy merger, Duke Energy Progress no longer designates interest rate contracts for regulated operations as cash flow hedges. As a result, pretax losses on open derivative contracts as of the date of the merger were reclassified from AOCI to Regulatory assets.
The amounts of pretax gains and losses recognized on undesignated contracts by type of derivative instrument and the line items in the Condensed Consolidated Statements of Operations and Comprehensive Income in which such gains and losses were included or deferred on the Condensed Consolidated Balance Sheets as regulatory assets or liabilities were as follows.

		Three Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues			$	3		$	-9
Fuel used in electric generation and purchased power ^(a)				-24			-35
Interest rate contracts
Interest expense				-3			-3
Total Pretax Losses Recognized in Earnings			$	-24		$	-47
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-11		$	15
Interest rate contracts^(c)
Regulatory asses				3			2
Total Pretax (Losses) Gains Recognized as Regulatory Assets or Liabilities			$	-8		$	17


		Nine Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues			$	10		$	-9
Fuel used in electric generation and purchased power^(a)				-53			-100
Interest rate contracts
Interest expense				-9			-3
Total Pretax Losses Recognized in Earnings			$	-52		$	-112
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-18		$	-34
Interest rate contracts^(c)
Regulatory assets				10			2
Total Pretax Losses Recognized as Regulatory Assets or Liabilities			$	-8		$	-32

(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
(b)	Amounts are recorded in regulatory assets and liabilities in the Condensed Consolidated Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.
(c)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

DUKE ENERGY FLORIDA
The fair value amounts of derivative contracts, and the line items in the Condensed Balance Sheets on which they were included were as follows. The fair value of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Duke Energy Florida nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

		30-Sep-13						31-Dec-12
(in millions)		Asset			Liability			Asset			Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current Liabilities: Other		$	―		$	―		$	―		$	1
Total Derivatives Designated as Hedging Instruments			―			―			―			1
Derivatives Not Designated as Hedging Instruments
Commodity contracts^(a)
Current Assets: Other			―			―			2			―
Investments and Other Assets: Other			―			―			7			―
Current Liabilities: Other			1			94			―			146
Deferred Credits and Other Liabilities: Other			1			79			―			123
Total Derivatives Not Designated as Hedging Instruments			2			173			9			269
Total Derivatives		$	2		$	173		$	9		$	270

(a)	Substantially all of these contracts receive regulatory treatment.

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Duke Energy Florida's financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. Duke Energy Florida may also have available accounts receivable or accounts payable to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	1		$	1			$	94		$	79
Gross amounts offset			-1			-1				-10			-13
Net amount subject to master netting			―			―				84			66
Amounts not subject to master netting			―			―				―			―
Net amounts recognized on the Condensed Balance Sheet		$	―	^(a)	$	―	^(b)		$	84	^(c)	$	66	^(d)

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	2		$	7			$	147		$	123
Gross amounts offset			―			―				-20			-29
Net amount subject to master netting			2			7				127			94
Amounts not subject to master netting			―			―				―			―
Net amounts recognized on the Condensed Balance Sheet		$	2	^(a)	$	7	^(b)		$	127	^(c)	$	94	^(d)

(a)	Included in Other within Current Assets on the Condensed Balance Sheet.
(b)	Included in Other within Investments and Other Assets on the Condensed Balance Sheet.
(c)	Included in Other within Current Liabilities on the Condensed Balance Sheet.
(d)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Balance Sheet.

Gains on cash flow hedges recorded or reclassified at Duke Energy Florida for the three months and nine months ended September 30, 2013 and 2012 were not material.

At September 30, 2012, $1 million of pretax deferred net losses on derivative instruments related to outstanding interest rate cash flow hedges were included as a component of AOCI. Effective with the Duke Energy merger, Duke Energy Florida no longer designates interest rate contracts for regulated operations as cash flow hedges. As a result, pretax losses on open derivative contracts as of the date of the merger were reclassified from AOCI to Regulatory assets.
The amounts of pretax gains and losses recognized on undesignated contracts by type of derivative instrument and the line items in the Condensed Statements of Operations and Comprehensive Income in which such gains and losses were included or deferred on the Condensed Balance Sheets as regulatory assets or liabilities were as follows.

		Three Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Fuel used in electric generation and purchased power^(a)			$	-45		$	-100
Interest rate contracts
Interest expense				-1			-1
Total Pretax Losses Recognized in Earnings			$	-46		$	-101
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-19		$	45
Interest rate contracts
Regulatory assets				1			―
Total Pretax (Losses) Gains Recognized as Regulatory Assets or Liabilities			$	-18		$	45


		Nine Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Fuel used in electric generation and purchased power^(a)			$	-105		$	-295
Interest rate contracts
Interest expense				-3			-1
Total Pretax Losses Recognized in Earnings			$	-108		$	-296
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(b)
Regulatory assets			$	-16		$	-74
Interest rate contracts
Regulatory assets				3			―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities			$	-13		$	-74

(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
(b)	Amounts are recorded in regulatory assets and liabilities in the Condensed Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.

DUKE ENERGY OHIO
The fair value amounts of derivative contracts, and the line items in the Condensed Consolidated Balance Sheets on which they were included were as follows. The fair values of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Duke Energy Ohio nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Consolidated Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

		30-Sep-13						31-Dec-12
(in millions)		Asset			Liability			Asset			Liability
Derivatives Designated as Hedging Instruments
Interest rate contracts
Current Assets: Other		$			$	―		$	2		$	―
Total Derivatives Designated as Hedging Instruments			―			―			2			―
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other			21			6			31			4
Investments and Other Assets: Other			158			103			81			51
Current Liabilities: Other			134			160			106			132
Deferred Credits and Other Liabilities: Other			1			17			―			4
Interest rate contracts
Current Liabilities: Other			―			―			―			1
Deferred Credits and Other Liabilities: Other			―			4			―			7
Total Derivatives Not Designated as Hedging Instruments			314			290			218			199
Total Derivatives		$	314		$	290		$	220		$	199

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Duke Energy Ohio's financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements, or with an ISO such as MISO or PJM. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. Duke Energy Ohio may also have available accounts receivable or accounts payable to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	155		$	159			$	165		$	120
Gross amounts offset			-141			-105				-154			-105
Net amount subject to master netting			14			54				11			15
Amounts not subject to master netting			―			―				1			4
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	14	^(a)	$	54	^(b)		$	12	^(c)	$	19	^(d)


		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	137		$	81			$	136		$	55
Gross amounts offset			-110			-51				-125			-51
Net amount subject to master netting			27			30				11			4
Amounts not subject to master netting			2			―				1			7
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	29	^(a)	$	30	^(b)		$	12	^(c)	$	11	^(d)

(a)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.
(b)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
(c)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.
(d)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

There were no gains or losses on cash flow hedges recorded or reclassified at Duke Energy Ohio for the three and nine months ended September 30, 2013 and 2012.
At September 30, 2013 and December 31, 2012, Duke Energy Ohio had no pretax deferred net gains or losses on derivative instruments related to cash flow hedges remaining in AOCI.
The amounts of the pretax gains and losses recognized on undesignated contracts by type of derivative instrument, and the line items in the Condensed Consolidated Statements of Operations and Comprehensive Income in which such gains and losses were included or deferred on the Condensed Consolidated Balance Sheets as regulatory assets or liabilities were as follows.

		Three Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Nonregulated electric, natural gas and other			$	5		$	-42
Fuel used in electric generation and purchased power - nonregulated				-2			―
Total Pretax (Losses) Gains Recognized in Earnings			$	3		$	-42


		Nine Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Nonregulated electric, natural gas and other			$	-8		$	33
Fuel used in electric generation and purchased power - nonregulated				-20			―
Interest rate contracts
Interest expense				-1			-1
Total Pretax (Losses) Gains Recognized in Earnings			$	-29		$	32
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets			$	―		$	-2
Regulatory liabilities							1
Interest rate contracts
Regulatory assets				3			―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities			$	3		$	-1

DUKE ENERGY INDIANA
The fair value amounts of derivative contracts, and the line items in the Condensed Consolidated Balance Sheets on which they were included were as follows. The fair values of derivative contracts are presented on a gross basis, even when the derivative instruments are subject to master netting arrangements. Duke Energy Indiana nets the fair value of derivative contracts subject to master netting arrangements with the same counterparty on the Condensed Consolidated Balance Sheets. Cash collateral associated with the derivative contracts were not netted against the fair value amounts in this table.

		30-Sep-13						31-Dec-12
(in millions)		Asset			Liability			Asset			Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts^(a)
Current Assets: Other		$	14		$	―		$	10		$	―
Interest rate contracts
Current Liabilities: Other			―			―			―			63
Total Derivatives Not Designated as Hedging Instruments			14			―			10			63
Total Derivatives		$	14		$	―		$	10		$	63

(a)	Substantially all of these contracts receive regulatory treatment.

The tables below show the balance sheet location of derivative contracts subject to enforceable master netting agreements and include collateral posted to offset the net position. This disclosure is intended to enable users to evaluate the effect of netting arrangements on Duke Energy Indiana's financial position. The amounts shown were calculated by counterparty.
Most derivatives are entered into with counterparties under enforceable master netting agreements. Derivatives entered into with a clearinghouse are usually over-collateralized due to the requirement to post initial margin upon entering into contracts. The amounts shown as offset are limited by the amount of exposure to a counterparty such that an over collateralized position at one counterparty is not allowed to reduce an under collateralized position at another counterparty. In addition to the amounts shown as offset in the table, Duke Energy Indiana may also have available accounts receivable or accounts payable to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		30-Sep-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Gross amounts recognized		$	14		$	―			$	―		$	―
Net amount subject to master netting			14			―				―			―
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	14	^(a)	$	―			$	―	^(b)	$	―

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current			Non-Current				Current			Non-Current
Amounts not subject to master netting			10			―				63			―
Net amounts recognized on the Condensed Consolidated Balance Sheet		$	10	^(a)	$	―			$	63	^(b)	$	―

(a)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.
(b)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.

Gains on cash flow hedges reclassified at Duke Energy Indiana for the three and nine months ended September 30, 2013 and 2012 were not material.

Pretax deferred net gains or losses on derivative instruments related to cash flow hedges remaining in AOCI for Duke Energy Indiana were not material at September 30, 2013 and 2012, respectively.
The amounts of the pretax gains and losses recognized on undesignated contracts by type of derivative instrument and line items in the Condensed Consolidated Statements of Operations and Comprehensive Income in which such gains and losses were included or deferred on the Condensed Consolidated Balance Sheets as regulatory assets or liabilities were as follows.

		Three Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets			$	2		$	11
Regulatory liabilities				6			―
Interest rate contracts^(a)
Regulatory assets				6			4
Total Pretax Gains Recognized as Regulatory Assets or Liabilities			$	14		$	15


		Nine Months Ended September 30,
(in millions)		2013				2012
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating Revenues			$	1		$	―
Fuel used in electric generation and purchased power				―			2
Total Pretax (Losses) Gains Recognized in Earnings			$	1		$	2
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory liabilities				10			33
Interest rate contracts^(a)
Regulatory assets				34			-5
Total Pretax Gains Recognized as Regulatory Assets or Liabilities			$	44		$	28

(a)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

CREDIT RISK
Certain of the Duke Energy Registrants' derivative contracts contain contingent credit features. These features may include (i) material adverse change clauses or payment acceleration clauses that could result in immediate payments, (ii) the posting of letters of credit or termination of the derivative contract before maturity if specific events occur, such as a credit rating downgrade below investment grade.
The following tables show information with respect to derivative contracts that are in a net liability position and contain objective credit-risk related payment provisions.

			30-Sep-13
(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
Aggregate fair value amounts of derivative instruments in a net liability position			$	481		$	211		$	82		$	129		$	268
Fair value of collateral already posted				138			26			5			21			106
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				200			185			77			108			15

			31-Dec-12
(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
Aggregate fair value amounts of derivative instruments in a net liability position			$	466		$	286		$	108		$	178		$	176
Fair value of collateral already posted				163			59			9			50			104
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				230			227			99			128			2

The Duke Energy Registrants have elected to offset cash collateral and fair values of derivative instruments. For amounts to be netted, the derivative instruments must be executed with the same counterparty under the same master netting agreement. Amounts disclosed in the table below represent the receivables related to the right to reclaim cash collateral and payables related to the obligation to return cash collateral under master netting arrangements. See Note 10 for additional information on fair value disclosures related to derivatives.

		30-Sep-13						31-Dec-12
(in millions)		Receivables			Payables			Receivables			Payables
Duke Energy
Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
Amounts not offset against net derivative positions			101			―			93			―
Progress Energy
Amounts offset against net derivative positions			26			―			58			―
Amounts not offset against net derivative positions			―			―			1			―
Duke Energy Progress
Amounts offset against net derivative positions			5			―			9			―
Duke Energy Florida
Amounts offset against net derivative positions			21			―			49			―
Amounts not offset against net derivative positions			―			―			1			―
Duke Energy Ohio
Amounts offset against net derivative positions			13			―			15			―
Amounts not offset against net derivative positions			92			―			92			―
Duke Energy Indiana
Amounts not offset against net derivative positions			3			―			―			―

Fair_Value_of_Financial_Assets

Fair Value of Financial Assets and Liabilities	9 Months Ended
Fair Value of Financial Assets and Liabilities	Sep. 30, 2013
Fair Value Of Financial Assets And Liabilities [Abstract]	'
Fair Value Of Financial Assets And Liabilities	'
	10. FAIR VALUE OF FINANCIAL ASSETS AND LIABILITIES
	Under existing accounting guidance, fair value is considered to be the exchange price in an orderly transaction between market participants to sell an asset or transfer a liability at the measurement date. The fair value definition focuses on an exit price. An exit price is the price that would be received to sell an asset or paid to transfer a liability. Fair value measurements require use of market data or assumptions market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, corroborated by market data, or generally unobservable. Valuation techniques are required to maximize use of observable inputs and minimize use of unobservable inputs. A midmarket pricing convention (the midpoint price between bid and ask prices) is permitted for use as a practical expedient.
	The Duke Energy Registrants classify recurring and non-recurring fair value measurements based on the fair value hierarchy. The hierarchy is prescribed by the accounting guidance for fair value. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels.
	Level 1—Unadjusted quoted prices in active markets for identical assets or liabilities an entity has the ability to access. An active market is one in which transactions for an asset or liability occur with sufficient frequency and volume to provide ongoing pricing information.
	Level 2—A fair value measurement utilizing inputs other than a quoted market price that are observable, either directly or indirectly, for an asset or liability. Level 2 inputs include, but are not limited to, (i) quoted prices for similar assets or liabilities in an active market, (ii) quoted prices for identical or similar assets or liabilities in markets that are not active, and (iii) inputs other than quoted market prices that are observable for the asset or liability, such as interest rate curves and yield curves observable at commonly quoted intervals, volatilities, credit risk and default rates. A Level 2 measurement cannot have more than an insignificant portion of its valuation based on unobservable inputs. Instruments in this category include non-exchange-traded derivatives, such as over-the-counter forwards, swaps and options; certain marketable debt securities; and financial instruments traded in less than active markets.
	Level 3—Any fair value measurement which includes unobservable inputs for an asset or liability for more than an insignificant portion of the valuation. These inputs may be used with internally developed methodologies that result in management's best estimate of fair value. Level 3 instruments may include longer-term instruments that extend into periods in which quoted prices or other observable inputs are not available.
	The fair value accounting guidance for financial instruments permits entities to elect to measure many financial instruments and certain other items at fair value that are not required to be accounted for at fair value under other GAAP. The Duke Energy Registrants have not elected to record any of these items at fair value. However, in the future, the Duke Energy Registrants may elect to measure certain financial instruments at fair value in accordance with this accounting guidance.
	Transfers between levels represent (i) assets or liabilities previously categorized as a higher level for which the inputs to the estimate became less observable or (ii) assets and liabilities that were previously classified as Level 2 or 3 for which the lowest significant input became more observable during the period. The Duke Energy Registrant's policy is to recognize transfers between levels of the fair value hierarchy at the end of the period. There were transfers out of level 3 at Duke Energy, Progress Energy, and Duke Energy Florida due to observability of inputs during the three and nine months ended September 30, 2013.
	Investments in equity securities
	Investments in equity securities, other than those accounted for as equity and cost method investments, are typically valued at the closing price in the principal active market as of the last business day of the reporting period. Principal active markets for equity prices include published exchanges such as NASDAQ and NYSE. Foreign equity prices are translated from their trading currency using the currency exchange rate in effect at the close of the principal active market. Prices have not been adjusted to reflect after-hours market activity. The majority of investments in equity securities are valued using Level 1 measurements. When (i) the Duke Energy Registrants lack the ability to redeem investments valued on a net asset value per share basis at net asset value per share in the near future or (ii) net asset value per share is not available at the measurement date, the fair value measurement of the investment is categorized as Level 3.
	Investments in available-for-sale auction rate securities
	Duke Energy and Duke Energy Carolinas hold auction rate securities for which an active market does not currently exist. Auction rate securities held are student loan securities. At September 30, 2013, approximately 80 percent are ultimately backed by the U.S. government and approximately 18 percent of these securities are AAA rated. As of September 30, 2013 and December 31, 2012, all of these auction rate securities are classified as long-term investments and are valued using Level 3 measurements. The methods and significant assumptions used to determine the fair values of the investment in auction rate debt securities represent estimations of fair value using internal discounted cash flow models. These models incorporate primarily management's own assumptions as to the term over which such investments will be recovered at par (ranging from 10 to 19 years), the current level of interest rates (less than 0.2%), and the appropriate risk-adjusted discount rates (up to 5.6% reflecting a tenor of up to 19 years). In preparing the valuations, all significant value drivers were considered, including the underlying collateral (primarily evaluated on the basis of credit ratings, parity ratios, and the percentage of loans backed by the U.S. government).
	There were no other-than-temporary impairments associated with investments in auction rate debt securities during the three and nine months ended September 30, 2013 or 2012.
	Investments in debt securities
	Most debt investments are valued based on a calculation using interest rate curves and credit spreads applied to the terms of the debt instrument (maturity and coupon interest rate) and consider the counterparty credit rating. Most debt valuations are Level 2 measurements. If the market for a particular fixed income security is relatively inactive or illiquid, the measurement is Level 3. U.S. Treasury debt is typically Level 1.
	Commodity derivatives
	The pricing for commodity derivatives is primarily a calculated value that incorporates forward prices and is adjusted for liquidity (bid-ask spread), credit or non-performance risk (after reflecting credit enhancements such as collateral), and discounted to present value. The primary difference between a Level 2 and a Level 3 measurement relates to the level of activity in forward markets for the commodity. If the market is relatively inactive, the measurement is deemed to be Level 3. Commodity derivatives with clearinghouses are classified as Level 1. For commodity derivative contracts classified as Level 3, Duke Energy utilizes internally-developed financial models based upon the income approach (discounted cash flow method) to measure fair values. The primary inputs to these models are forward commodity prices used to develop forward price curves for the respective instrument. Pricing inputs are derived from published exchange transaction prices and other observable or public data sources. In the absence of observable market information that supports the pricing inputs, there is a presumption the transaction price is equal to the last observable price for a similar period. For commodity derivative contracts classified as Level 3, pricing inputs for natural gas and electricity forward price curves are not observable for the full term of the related contracts. In isolation, increases (decreases) in unobservable natural gas forward prices would result in favorable (unfavorable) fair value adjustments for gas purchase contracts. In isolation, increases (decreases) in unobservable electricity forward prices would result in unfavorable (favorable) fair value adjustments for electricity sales contracts. Duke Energy regularly evaluates and validates pricing inputs used to estimate fair value of gas purchase contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.
	Interest rate derivatives
	Most over-the-counter interest rate contract derivatives are valued using financial systems that utilize observable inputs for similar instruments and are classified as Level 2. Such systems are standard in the market and are commonly used across industries to value derivative contracts. The Duke Energy Registrants utilize various inputs and factors including market data and assumptions market participants would use in pricing assets or liabilities as well as assumptions about risks inherent in the inputs to valuation technique. Inputs and factors may include forward interest rate curves, notional amounts, interest rates and credit quality of the Duke Energy Registrants and their counterparties.
	Goodwill and Long-lived Assets
	See Note 12, Goodwill and Intangible Assets, to the Consolidated Financial Statements included in Duke Energy's Annual Report on Form 10-K for the year ended December 31, 2012 for a discussion of the valuation of goodwill and long-lived assets.
	DUKE ENERGY
	The following tables provide fair value amounts for assets and liabilities recorded on Duke Energy's Condensed Consolidated Balance Sheets. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Duke Energy's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 8. See Note 9 for additional information related to investments by major security type.

				30-Sep-13
	(in millions)			Total Fair Value			Level 1			Level 2			Level 3
	Investments in available-for-sale auction rate securities^(a)			$	25		$	―		$	―		$	25
	Nuclear decommissioning trust fund equity securities				3,280			3,199			59			22
	Nuclear decommissioning trust fund debt securities				1,525			392			1,083			50
	Other trading and available-for-sale equity securities^(b)				93			83			10			―
	Other trading and available-for-sale debt securities^(c)				414			57			357			―
	Derivative assets^(b)				127			32			22			73
		Total assets			5,464			3,763			1,531			170
	Derivative liabilities^(d)				-473			-15			-347			-111
		Net assets		$	4,991		$	3,748		$	1,184		$	59


				31-Dec-12
	(in millions)			Total Fair Value			Level 1			Level 2			Level 3
	Investments in available-for-sale auction rate securities^(a)			$	29		$	―		$	―		$	29
	Nuclear decommissioning trust fund equity securities				2,837			2,762			54			21
	Nuclear decommissioning trust fund debt securities				1,405			317			1,040			48
	Other trading and available-for-sale equity securities^(b)				72			63			9			―
	Other trading and available-for-sale debt securities^(c)				602			40			562			―
	Derivative assets^(b)				103			18			22			63
		Total assets			5,048			3,200			1,687			161
	Derivative liabilities^(d)				-756			-17			-591			-148
		Net assets		$	4,292		$	3,183		$	1,096		$	13

	(a)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
	(b)	Included in Other within Current Assets and Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
	(c)	Included in Other within Investments and Other Assets and Short-term Investments on the Condensed Consolidated Balance Sheets.
	(d)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.

	The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

				Three Months Ended September 30, 2013
	(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
	Balance at June 30, 2013			$	26		$	71		$	-87		$	10
	Total pretax realized or unrealized gains (losses) included in earnings:
		Revenue: Regulated electric			―			―			4			4
		Revenue: Nonregulated electric, natural gas, and other			―			―			9			9
	Total pretax gains included in other comprehensive income:
	Gains on available for sale securities and other			1			―			―			1
Purchases, sales, issuances and settlements:
	Purchases			―			2			―			2
	Sales			―			-2			―			-2
	Issuances			―			―			4			4
	Settlements			-2			―			-3			-5
Transfers in and out of Level 3 due to observability of inputs				―			―			34			34
Total gains (losses) included on the Consolidated Balance Sheet as regulatory assets or liabilities				―			1			1			2
Balance at September 30, 2013			$	25		$	72		$	-38		$	59
Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
	Revenue: Regulated electric		$	―		$	―		$	3		$	3
	Revenue: Nonregulated electric, natural gas, and other			―			―			-2			-2
Total			$	―		$	―		$	1		$	1


			Three Months Ended September 30, 2012
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at June 30, 2012			$	41		$	64		$	-19		$	86
Amounts acquired in Progress Merger				―			―			-30			-30
Total pretax realized or unrealized gains (losses) included in earnings:
	Revenue: Regulated electric			―			―			12			12
	Revenue: Nonregulated electric, natural gas, and other			―			―			-6			-6
Total pretax gains included in other comprehensive income:
Purchases, sales, issuances and settlements:
	Purchases			―			1			―			1
	Issuances			―			―			-24			-24
	Settlements						―			-10			-10
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			1			2			3
Balance at September 30, 2012			$	41		$	66		$	-75		$	32


			Nine Months Ended September 30, 2013
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at December 31, 2012			$	29		$	69		$	-85		$	13
Total pretax realized or unrealized gains (losses) included in earnings:
	Revenue: Regulated electric			―			―			5			5
	Revenue: Nonregulated electric, natural gas, and other			―			―			-13			-13
Total pretax gains included in other comprehensive income:
	Losses on available for sale securities and other			-1			―			―			-1
Purchases, sales, issuances and settlements:
	Purchases			―			5			21			26
	Sales			―			-5			―			-5
	Issuances			―			―			9			9
	Settlements			-3			―			-5			-8
Transfers in and out of Level 3 due to observability of inputs				―			―			34			34
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			3			-4			-1
Balance at September 30, 2013			$	25		$	72		$	-38		$	59
Pretax amounts included in the Condensed Consolidated Statement of Operations related to Level 3 measurements outstanding at September 30, 2013
	Revenue: Regulated electric		$	―		$	―		$	5		$	5
	Revenue: Nonregulated electric, natural gas, and other			―			―			-26			-26
Total			$	―		$	―		$	-21		$	-21


			Nine Months Ended September 30, 2012
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at December 31, 2011			$	71		$	53		$	-39		$	85
Amounts acquired in Progress Energy Merger				―			―			-30			-30
Total pretax realized or unrealized losses included in earnings:
	Revenue: Regulated electric			―			―			37			37
	Revenue: Nonregulated electric, natural gas, and other			―			―			-9			-9
Total pretax gains included in other comprehensive income:
	Gains on available for sale securities and other			9			―			―			9
Purchases, sales, issuances and settlements:
	Purchases			―			10			22			32
	Issuances			―			―			-24			-24
	Settlements			-39			―			-34			-73
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			3			2			5
Balance at September 30, 2012			$	41		$	66		$	-75		$	32
Pretax amounts included in the Condensed Consolidated Statement of Operations related to Level 3 measurements outstanding at September 30, 2012.
	Revenue: Nonregulated electric, natural gas, and other		$	―		$	―		$	5		$	5
Total			$	―		$	―		$	5		$	5

DUKE ENERGY CAROLINAS
The following tables provide fair value amounts for assets and liabilities recorded on Duke Energy Carolinas' Condensed Consolidated Balance Sheets at fair value. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Duke Energy Carolinas' assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 8. See Note 9 for additional information related to investments by major security type.

				30-Sep-13
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Investments in available-for-sale auction rate securities^(a)			$	3		$	―		$	―		$	3
Nuclear decommissioning trust fund equity securities				1,790			1,715			53			22
Nuclear decommissioning trust fund debt securities				883			220			613			50
	Total assets			2,676			1,935			666			75
Derivative liabilities^(b)				-4			―			―			-4
	Net assets		$	2,672		$	1,935		$	666		$	71


			31-Dec-12
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Investments in available-for-sale auction rate securities^(a)			$	3		$	―		$	―		$	3
Nuclear decommissioning trust fund equity securities				1,592			1,523			48			21
Nuclear decommissioning trust fund debt securities				762			155			559			48
	Total assets			2,357			1,678			607			72
Derivative liabilities^(b)				-12			―			―			-12
	Net Assets		$	2,345		$	1,678		$	607		$	60

(a)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Three Months Ended September 30, 2013
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at June 30, 2013			$	3		$	71		$	-4		$	70
Purchases, sales, issuances and settlements:
	Purchases			―			2			―			2
	Sales			―			-2			―			-2
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			1			―			1
Balance at September 30, 2013			$	3		$	72		$	-4		$	71


			Three Months Ended September 30, 2012
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at June 30, 2012			$	6		$	64		$	―		$	70
Purchases, sales, issuances and settlements:
	Purchases			―			1			―			1
	Issuances			―			―			-14			-14
	Settlements			―			―			2			2
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			1			―			1
Balance at September 30, 2012			$	6		$	66		$	-12		$	60


			Nine Months Ended September 30, 2013
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at December 31, 2012			$	3		$	69		$	-12		$	60
Purchases, sales, issuances and settlements:
	Purchases			―			5			―			5
	Sales			―			-5			―			-5
	Settlements			―			―			8			8
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				―			3			―			3
Balance at September 30, 2013			$	3		$	72		$	-4		$	71
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
	Operating Revenues		$	―		$	―		$	-4		$	-4
Total			$	―		$	―		$	-4		$	-4

			Nine Months Ended September 30, 2012
(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total
Balance at December 31, 2011			$	12		$	53		$	―		$	65
Total pretax gains included in other comprehensive income:
	Gains on available for sale securities and other			2			―			―			2
Purchases, sales, issuances and settlements:
	Purchases			―			10			―			10
	Issuances			―			―			-14			-14
	Settlements			-8			―			2			-6
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			3			―			3
Balance at September 30, 2012			$	6		$	66		$	-12		$	60

PROGRESS ENERGY
The following tables provide fair value amounts for assets and liabilities recorded on Progress Energy's Condensed Consolidated Balance Sheets. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Progress Energy's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 8. See Note 9 for additional information related to investments by major security type.

			30-Sep-13
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities			$	1,489		$	1,483		$	6		$	―
Nuclear decommissioning trust fund debt securities and other				642			172			470			―
Other trading and available-for-sale debt securities and other^(a)				55			19			36			―
	Total assets			2,186			1,674			512			―
Derivative liabilities^(c)				-282			―			-282			―
	Net assets		$	1,904		$	1,674		$	230		$	―


			31-Dec-12
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities			$	1,245		$	1,239		$	6		$	―
Nuclear decommissioning trust fund debt securities and other				643			162			481			―
Other trading and available-for-sale debt securities and other^(a)				57			17			40			―
Derivative assets^(b)				11			―			11			―
	Total assets			1,956			1,418			538			―
Derivative liabilities^(c)				-440			―			-402			-38
	Net assets		$	1,516		$	1,418		$	136		$	-38

(a)	Included in Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
(b)	Included in Other Current Assets within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Three Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	-35		$	-30
Total pretax realized or unrealized gains included in earnings:
	Revenue: Regulated electric				―			2
Purchases, sales, issuances and settlements:
	Issuances				2			-16
	Settlements				―			4
Total (losses) gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					-1			4
Transfers in and out of Level 3 due to observability of inputs					34			―
Balance at end of period				$	―		$	-36


			Derivatives (net)
			Nine Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	-38		$	-24
Total pretax realized or unrealized gains included in earnings:
	Operating Revenues				―			2
Purchases, sales, issuances and settlements:
	Issuances				10			-16
	Settlements				―			4
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					-6			-2
Transfers in and out of Level 3 due to observability of inputs					34			―
Balance at end of period				$	―		$	-36
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
	Revenue: Regulated electric			$	10		$	―
Total				$	10		$	―

DUKE ENERGY PROGRESS
The following tables provide fair value amounts for assets and liabilities recorded on Duke Energy Progress' Condensed Consolidated Balance Sheets. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Duke Energy Progress' assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral which are disclosed in Note 8. See Note 9 for additional information related to investments by major security type.

			30-Sep-13
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities			$	985		$	985		$	―		$	―
Nuclear decommissioning trust fund debt securities and other				440			112			328			―
Other trading and available-for-sale debt securities and other^(a)				2			2			―			―
	Total assets			1,427			1,099			328			―
Derivative liabilities^(c)				-107			―			-107			―
	Net assets		$	1,320		$	1,099		$	221		$	―


			31-Dec-12
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities			$	811		$	811		$	―		$	―
Nuclear decommissioning trust fund debt securities and other				448			119			329			―
Other trading and available-for-sale debt securities and other^(a)				3			3			―			―
Derivative assets^(b)				2			―			2			―
	Total assets			1,264			933			331			―
Derivative liabilities^(c)				-166			―			-128			-38
	Net assets		$	1,098		$	933		$	203		$	-38

(a)	Included in Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
(b)	Included in Other Current Assets within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Three Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	-35		$	-28
Total pretax realized or unrealized gains (losses) included in earnings:
	Operating Revenues				―			2
Purchases, sales, issuances and settlements:
	Issuances							-16
	Settlements				2			4
Total (losses) gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					-1			2
Transfers in and out of Level 3 due to observability of inputs					34			―
Balance at end of period				$	―		$	-36
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
	Revenue: Regulated electric			$	1		$	―
Total				$	1		$	―


			Derivatives (net)
			Nine Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	-38		$	-24
Total pretax realized or unrealized gains (losses) included in earnings:
	Operating Revenues				―			2
Purchases, sales, issuances and settlements:
	Issuances				9			-16
	Settlements				―			4
Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					-5			-2
Transfers in and out of Level 3 due to observability of inputs					34			―
Balance at end of period				$	―		$	-36
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
	Revenue: Regulated electric			$	10		$	―
Total				$	10		$	―

DUKE ENERGY FLORIDA
The following tables provide fair value amounts for assets and liabilities recorded on Duke Energy Florida's Condensed Balance Sheets. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Duke Energy Florida's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral which are disclosed in Note 8. See Note 9 for additional information related to investments by major security type.

			30-Sep-13
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities			$	505		$	499		$	6		$	―
Nuclear decommissioning trust fund debt securities and other				202			60			142			―
Other trading and available-for-sale debt securities and other^(a)				39			2			37			―
	Total assets			746			561			185			―
Derivative liabilities^(b)				-171			―			-171			―
	Net assets		$	575		$	561		$	14		$	―


			31-Dec-12
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities			$	435		$	429		$	6		$	―
Nuclear decommissioning trust fund debt securities and other				194			43			151			―
Other trading and available-for-sale debt securities and other^(a)				43			3			40			―
Derivative assets				9			―			9			―
	Total assets			681			475			206			―
Derivative liabilities^(b)				-270			―			-270			―
	Net assets (liabilities)		$	411		$	475		$	-64		$	―

(a)	Included in Other within Investments and Other Assets in the Condensed Balance Sheets.
(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Balance Sheets

DUKE ENERGY OHIO
The following tables provide fair value amounts for assets and liabilities recorded on Duke Energy Ohio's Condensed Consolidated Balance Sheets. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Duke Energy Ohio's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 8.

			30-Sep-13
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Derivative assets^(a)			$	70		$	49		$	―		$	21
Derivative liabilities^(b)				-46			-14			-5			-27
	Net assets (liabilities)		$	24		$	35		$	-5		$	-6


			31-Dec-12
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Derivative assets^(a)			$	59		$	48		$	2		$	9
Derivative liabilities^(b)				-38			-15			-8			-15
	Net assets (liabilities)		$	21		$	33		$	-6		$	-6

(a)	Included in Other within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Three Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	-19		$	-2
Total pretax realized or unrealized gains (losses) included in earnings:
	Revenue: Regulated electric				―			1
	Revenue: Nonregulated electric and other				11			-6
Purchases, sales, issuances and settlements:
	Settlements				2			-1
Balance at end of period				$	-6		$	-8
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013:
	Revenue: Nonregulated electric and other			$	-3		$	―
Total				$	-3		$	―


			Derivatives (net)
			Nine Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	-6		$	-3
Total pretax realized or unrealized gains (losses) included in earnings:
	Revenue: Regulated electric				―			1
	Revenue: Nonregulated electric and other				-4			-5
Purchases, sales, issuances and settlements:
	Purchases				1			―
	Settlements				―			1
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					3			-2
Balance at end of period				$	-6		$	-8
Pretax amounts included in the Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013:
	Revenue: Nonregulated electric and other			$	-16		$	1
Total				$	-16		$	1

DUKE ENERGY INDIANA
The following tables provide fair value amounts for assets and liabilities recorded on Duke Energy Indiana's Condensed Consolidated Balance Sheets. Financial assets and liabilities are classified in their entirety based on the lowest level of input significant to the fair value measurement. Duke Energy Indiana's assessment of the significance of a particular input to the fair value measurement requires judgment and may affect valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. Derivative amounts in the table below exclude cash collateral which are disclosed in Note 8. See Note 9 for additional information related to investments by major security type.

			30-Sep-13
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Available-for-sale equity securities^(a)			$	60		$	60		$	―		$	―
Available-for-sale debt securities^(a)				28			―			28			―
Derivative assets^(b)				14			―			―			14
	Total assets			102			60			28		$	14
	Net assets (liabilities)		$	102		$	60		$	28		$	14


			31-Dec-12
(in millions)			Total Fair Value			Level 1			Level 2			Level 3
Available-for-sale equity securities^(a)			$	49		$	49		$	―		$	―
Available-for-sale debt securities^(a)				29			―			29			―
Derivative assets^(b)				10			―			―			10
	Total assets			88			49			29		$	10
Derivative liabilities^(c)				-63			―			-63			―
	Net assets (liabilities)		$	25		$	49		$	-34		$	10

(a)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
(b)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheets.
(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Three Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	18		$	22
Total pretax realized or unrealized gains (losses) included in earnings:
	Operating Revenues				3			11
Purchases, sales, issuances and settlements:
	Settlements				-10			-16
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					3			―
Balance at end of period				$	14		$	17


			Derivatives (net)
			Nine Months Ended September 30,
(in millions)					2013			2012
Balance at beginning of period				$	10		$	4
Total pretax realized or unrealized gains (losses) included in earnings:
	Operating Revenues				5			35
Purchases, sales, issuances and settlements:
	Purchases				20			―
	Sales				―			22
	Settlements				-23			-45
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					2			1
Balance at end of period				$	14		$	17

QUANTITATIVE DISCLOSURES ABOUT UNOBSERVABLE INPUTS

The following table includes quantitative information about the Duke Energy Registrants' derivatives classified as Level 3.

		30-Sep-13
Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
Duke Energy
Commodity natural gas contracts		$	-43		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.47	-	10.36
FERC mitigation power sale agreements			-4		Discounted cash flow		Forward electricity curves - price per megawatt-hour (MWh)		25.79	-	48.34
Financial transmission rights (FTRs)			15		RTO market pricing		FTR price - per MWh		-1.53	-	10.86
Commodity power contracts			5		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19
Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	122.64
Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		29.3	-	100.8
Reserves			-12				Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives		$	-38
Duke Energy Carolinas
FERC mitigation power sale agreements		$	-4		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	-	48.34
Duke Energy Ohio
Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	-0.09	-	0.46
Commodity power contracts			13		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19
Commodity natural gas contracts			-9		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.47	-	4.55
Reserves			-11				Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives		$	-6
Duke Energy Indiana
Financial transmission rights (FTRs)		$	14		RTO market pricing		FTR price - per MWh	$	-1.53	-	10.86


		31-Dec-12
Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
Duke Energy
Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
Reserves			-12				Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives		$	-85
Duke Energy Carolinas
FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
Progress Energy
Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
Total Level 3 derivatives		$	-38
Duke Energy Progress
Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
Total Level 3 derivatives		$	-38
Duke Energy Ohio
Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
Reserves			-11				Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives		$	-6
Duke Energy Indiana
Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

OTHER FAIR VALUE DISCLOSURES

The fair value and book value of long-term debt, including current maturities, is summarized in the following table. Judgment is required in interpreting market data to develop estimates of fair value. Accordingly, estimates determined are not necessarily indicative of amounts the Duke Energy Registrants could have settled in current markets. The fair value of long-term debt is determined using Level 2 measurements.

		30-Sep-13						31-Dec-12
(in millions)		Book Value			Fair Value			Book Value			Fair Value
Duke Energy ^(a)		$	39,709		$	42,142		$	39,461		$	44,001
Duke Energy Carolinas^(b)			8,739			9,445			8,741			10,096
Progress Energy			13,815			14,989			14,428			16,563
Duke Energy Progress			4,936			5,053			4,840			5,277
Duke Energy Florida			4,887			5,424			5,320			6,222
Duke Energy Ohio			2,188			2,263			1,997			2,117
Duke Energy Indiana			3,798			4,143			3,702			4,268

(a)	Includes book value of Non-recourse long-term debt of variable interest entities of $1,265 million and $852 million September 30, 2013 and December 31, 2012, respectively.
(b)	Includes book value of Non-recourse long-term debt of variable interest entities of $300 million at both September 30, 2013 and December 31, 2012, respectively.

At both September 30, 2013 and December 31, 2012, the fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and non-recourse notes payable of variable interest entities are not materially different from their carrying amounts because of the short-term nature of these instruments and/or because the stated rates approximate market rates.

Investments_in_Debt_and_Equity

Investments in Debt and Equity Securities	9 Months Ended
Investments in Debt and Equity Securities	Sep. 30, 2013
Investments In Debt And Equity Securities [Abstract]	'
Investments In Debt And Equity Securities	'
	9. Investments in Debt and Equity Securities
	The Duke Energy Registrants classify their investments in debt and equity securities as either trading or available-for-sale.
	Investments in debt and equity securities are classified as either short-term investments or long-term investments based on management's intent and ability to sell these securities, taking into consideration illiquidity factors in the current markets.
	TRADING SECURITIES
	Investments in debt and equity securities held in Grantor Trusts associated with certain deferred compensation plans and certain other investments are classified as trading securities. These investments are reported at fair value in the Condensed Consolidated Balance Sheets. Net realized and unrealized gains and losses are included in earnings each period. The fair value of these investments was $17 million at September 30, 2013 and $33 million at December 31, 2012.
	AVAILABLE-FOR-SALE SECURITIES
	All other investments in debt and equity securities are classified as available-for-sale securities. Available-for-sale securities are also reported at fair value on the Condensed Consolidated Balance Sheets. Unrealized gains and losses are excluded from earnings and reported either as a (i) regulatory asset or liability, or (ii) a component of other comprehensive income until realized.
	Duke Energy's available-for-sale securities are primarily comprised of investments held in (i) the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida, (ii) Grantor Trusts at Duke Energy Indiana, Duke Energy Florida and Duke Energy Progress related to OPEB plans (iii) Duke Energy's captive insurance investment portfolio, (iv) Duke Energy's foreign operations investment portfolio and (v) Duke Energy and Duke Energy Carolinas' auction rate debt securities portfolio.
	Duke Energy holds corporate debt securities that were purchased using excess cash from its foreign operations. These investments are classified as Short-term investments on the Condensed Consolidated Balance Sheet and are available for current operations of Duke Energy's foreign business. The fair value of these investments was $118 million as of September 30, 2013 and $333 million as of December 31, 2012.
	Duke Energy classifies all other investments in debt and equity securities as long-term, unless otherwise noted.
	NDTF and Grantor Trust
	The investments within the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida and the Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana Grantor Trusts (Investment Trusts) are managed by independent investment managers with discretion to buy, sell, and invest pursuant to the objectives set forth by the trust agreements. The Duke Energy Registrants have limited oversight of the day-to-day management of these investments. As a result, the ability to hold investments in unrealized loss positions is outside the control of the Duke Energy Registrants. Accordingly, all unrealized gains and losses associated with debt and equity securities within the Investment Trusts are considered other-than-temporary impairments and are recognized immediately. Pursuant to regulatory accounting, substantially all unrealized gains and losses associated with investments within the Investment Trusts are deferred as a regulatory asset or liability. As a result, there is no immediate impact on earnings of the Duke Energy Registrants.
	Other Available for Sale Securities
	Unrealized gains and losses on all other available-for-sale securities are included in other comprehensive income until realized, unless it is determined the carrying value of an investment is other-than-temporarily impaired. If an other-than-temporary impairment exists, the unrealized loss may be included in earnings based on the criteria discussed below.
	The Duke Energy Registrants analyze all investment holdings each reporting period to determine whether a decline in fair value should be considered other-than-temporary. Criteria used to evaluate whether an impairment associated with equity securities is other-than-temporary includes, but is not limited to,(i) the length of time over which the market value has been lower than the cost basis of the investment, (ii) the percentage decline compared to the cost of the investment, and (iii) management's intent and ability to retain its investment in the issuer for a period of time sufficient to allow for any anticipated recovery in market value. If a decline in fair value is determined to be other-than-temporary, the investment is written down to its fair value through a charge to earnings.
	If the entity does not have an intent to sell a debt security and it is not more likely than not that management will be required to sell the debt security before the recovery of its cost basis, the impairment write-down to fair value would be recorded as a component of other comprehensive income, except for when it is determined that a credit loss exists. In determining whether a credit loss exists, management considers, among other things, (i) the length of time and the extent to which the fair value has been less than the amortized cost basis, (ii) changes in the financial condition of the issuer of the security, or in the case of an asset backed security, the financial condition of the underlying loan obligors, (iii) consideration of underlying collateral and guarantees of amounts by government entities, (iv) ability of the issuer of the security to make scheduled interest or principal payments, and (v) any changes to the rating of the security by rating agencies. If a credit loss exists, the amount of impairment write-down to fair value is split between credit loss and other factors. The amount related to credit loss is recognized in earnings. The amount related to other factors is recognized in other comprehensive income. There were no credit losses as of September 30, 2013 and December 31, 2012. For the Duke Energy Registrants, there were no other-than-temporary impairments for debt or equity securities as of September 30, 2013 and December 31, 2012. Accordingly, all changes in the market value of investments other than those held in the Investment Trusts, which receive regulatory accounting as discussed above, were reflected as a component of other comprehensive income in 2013 and 2012.
	See Note 10 for additional information related to fair value measurements for investments in auction rate debt securities.
	DUKE ENERGY

	The following table presents the estimated fair value of short-term and long-term investments for Duke Energy. For investments held within the NDTF and investments within Grantor Trusts, unrealized holding gains and losses are recognized immediately and recorded as Regulatory assets or Regulatory liabilities on the Condensed Consolidated Balance Sheets.

			30-Sep-13											31-Dec-12
	(in millions)		Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value			Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value
	NDTF
	Cash and cash equivalents			$	―			$	―		$	111			$	―			$	―		$	105
	Equity securities				1,560				13			3,280				1,132				19			2,837
	Corporate debt securities				9				6			323				21				1			338
	Municipal bonds				5				7			213				12				1			194
	U.S. government bonds				14				8			712				24				1			625
	Other debt securities				17				4			167				10				1			164
	Total NDTF				1,605				38			4,806				1,199				23			4,263
	Other Investments
	Cash and cash equivalents				―				―			21				―				―			17
	Equity securities				22				―			83				10				―			63
	Corporate debt securities				1				2			178				2				―			381
	Municipal bonds				2				2			80				4				1			70
	U.S. government bonds				―				―			38				―				―			23
	Other debt securities				―				1			92				1				―			86
	Auction rate securities				―				7			25				―				6			29
	Total Other Investments^(a)				25				12			517				17				7			669
	Total Investments			$	1,630			$	50		$	5,323			$	1,216			$	30		$	4,932

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

	The table below summarizes the maturity date for debt securities held by Duke Energy. The table below excludes auction rate securities based on the stated maturity date. See Note 10 for information about fair value measurements related to investments in auction rate debt securities.

	(in millions)		30-Sep-13
	Due in one year or less			$	185
	Due after one through five years				394
	Due after five through 10 years				434
	Due after 10 years				790
	Total			$	1,803

	Realized gains and losses, which were determined on a specific identification basis, from sales of Duke Energy's available-for-sale securities were as follows.

			Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)				2013		2012					2013		2012
	Realized gains			$	72		$	30			$	135		$	80
	Realized losses				16			12				38			14

	DUKE ENERGY CAROLINAS

	The following table presents the estimated fair value of short-term and long-term investments for Duke Energy Carolinas. For investments held within the NDTF, unrealized holding gains and losses are recognized immediately and recorded as Regulatory assets or Regulatory liabilities on the Condensed Consolidated Balance Sheets.

		30-Sep-13											31-Dec-12
(in millions)		Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value			Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value
NDTF
Cash and cash equivalents			$	―			$	―		$	46			$	―			$	―		$	40
Equity securities				828				5			1,790				600				5			1,592
Corporate debt securities				4				5			236				11				1			250
Municipal bonds				―				1			52				2				―			40
U.S. government bonds				5				4			396				10				―			304
Other debt securities				17				4			147				9				2			135
Total NDTF				854				19			2,667				632				8			2,361
Other Investments
Auction rate securities				―				1			3				―				1			3
Total Other Investments^(a)				―				1			3				―				1			3
Total Investments			$	854			$	20		$	2,670			$	632			$	9		$	2,364

(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities held by Duke Energy Carolinas. The table below excludes auction rate securities based on the stated maturity date. See Note 10 for information about fair value measurements related to investments in auction rate debt securities.

(in millions)		30-Sep-13
Due in one year or less			$	23
Due after one through five years				175
Due after five through 10 years				223
Due after 10 years				410
Total			$	831

Realized gains and losses, which were determined on a specific identification basis, from sales of Duke Energy Carolinas' available-for-sale securities were as follows.

		Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)				2013		2012					2013		2012
Realized gains			$	49		$	19			$	95		$	65
Realized losses				1			5				11			7

PROGRESS ENERGY

The following table presents the estimated fair value of short-term and long-term investments for Progress Energy. For investments held within the NDTF and investments within Grantor Trusts, unrealized holding gains and losses are recognized immediately and recorded as Regulatory assets or Regulatory liabilities on the Condensed Consolidated Balance Sheets.

		30-Sep-13											31-Dec-12
(in millions)		Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value			Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value
NDTF
Cash and cash equivalents			$	―			$	―		$	65			$	―			$	―		$	65
Equity securities				732				8			1,490				532				14			1,245
Corporate debt securities				5				1			87				9				―			89
Municipal bonds				5				6			161				11				1			154
U.S. government bonds				9				4			316				14				―			321
Other debt securities				―				―			20				1				―			28
Total NDTF				751				19			2,139				567				15			1,902
Other Investments
Cash and cash equivalents				―				―			21				―				―			17
Municipal bonds				1				1			36				3				―			40
Total Other Investments^(a)				1				1			57				3				―			57
Total Investments			$	752			$	20		$	2,196			$	570			$	15		$	1,959

(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities held by Progress Energy.

(in millions)		30-Sep-13
Due in one year or less			$	14
Due after one through five years				162
Due after five through 10 years				150
Due after 10 years				294
Total			$	620

Realized gains and losses, which were determined on a specific identification basis, from sales of Progress Energy's available-for-sale securities were as follows.

		Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)				2013		2012					2013		2012
Realized gains			$	22		$	8			$	37		$	23
Realized losses				11			6				20			12

DUKE ENERGY PROGRESS

The following table presents the estimated fair value of short-term and long-term investments for Duke Energy Progress. For investments held within the NDTF and investments within Grantor Trusts, unrealized holding gains and losses are recognized immediately and recorded as Regulatory assets or Regulatory liabilities on the Condensed Consolidated Balance Sheets.

		30-Sep-13											31-Dec-12
(in millions)		Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value			Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value
NDTF
Cash and cash equivalents			$	―			$	―		$	30			$	―			$	―		$	55
Equity securities				472				7			985				337				11			811
Corporate debt securities				5				1			83				8				―			78
Municipal bonds				2				4			103				4				―			80
U.S. government bonds				8				3			225				13				―			241
Other debt securities				―				―			9				1				―			10
Total NDTF				487				15			1,435				363				11			1,275
Other Investments
Cash and cash equivalents				―				―			2				―				―			3
Total Other Investments^(a)				―				―			2				―				―			3
Total Investments			$	487			$	15		$	1,437			$	363			$	11		$	1,278

(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities held by Duke Energy Progress.

(in millions)		30-Sep-13
Due in one year or less			$	6
Due after one through five years				125
Due after five through 10 years				88
Due after 10 years				201
Total			$	420

Realized gains and losses, which were determined on a specific identification basis, from sales of Duke Energy Progress' available-for-sale securities were as follows.

		Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)				2013		2012					2013		2012
Realized gains			$	7		$	4			$	15		$	14
Realized losses				2			2				6			5

DUKE ENERGY FLORIDA

The following table presents the estimated fair value of short-term and long-term investments for Duke Energy Florida. For investments held within the NDTF and investments within Grantor Trusts, unrealized holding gains and losses are recognized immediately and recorded as Regulatory assets or Regulatory liabilities on the Condensed Balance Sheets.

		30-Sep-13											31-Dec-12
(in millions)		Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value			Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value
NDTF
Cash and cash equivalents			$	―			$	―		$	35			$	―			$	―		$	10
Equity securities				260				1			505				194				4			434
Corporate debt securities				―				―			4				1				―			11
Municipal bonds				3				2			58				7				―			74
U.S. government bonds				1				1			91				1				―			80
Other debt securities				―				―			11				1				―			18
Total NDTF				264				4			704				204				4			627
Other Investments
Cash and cash equivalents				―				―			4				―				―			1
Municipal bonds				1				1			37				3				―			40
Total Other Investments^(a)				1				1			41				3				―			41
Total Investments			$	265			$	5		$	745			$	207			$	4		$	668

(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Balance Sheets.

The table below summarizes the maturity date for debt securities held by Duke Energy Florida.

(in millions)		30-Sep-13
Due in one year or less			$	8
Due after one through five years				37
Due after five through 10 years				62
Due after 10 years				94
Total			$	201

Realized gains and losses, which were determined on a specific identification basis, from sales of Duke Energy Florida's available-for-sale securities were as follows.

		Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)				2013		2012					2013			2012
Realized gains			$	14		$	4			$	22		$	9
Realized losses				9			4				13			7

DUKE ENERGY INDIANA

The following table presents the estimated fair value of short-term and long-term investments for Duke Energy Indiana. For investments held within Grantor Trusts, unrealized holding gains and losses on these investments are recognized immediately and recorded as Regulatory assets or Regulatory liabilities on the Condensed Consolidated Balance Sheets.

		30-Sep-13											31-Dec-12
(in millions)		Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value			Gross Unrealized Holding Gains				Gross Unrealized Holding Losses				Estimated Fair Value
Other Investments
Equity securities			$	19			$	―		$	60			$	9			$	―		$	50
Municipal bonds				―				1			28				1				―			28
Total Other Investments^(a)				19				1			88				10				―			78
Total Investments			$	19			$	1		$	88			$	10			$	―		$	78

(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

The table below summarizes the maturity date for debt securities held by Duke Energy Indiana.

(in millions)		30-Sep-13
Due in one year or less			$	2
Due after one through five years				21
Due after five through 10 years				4
Due after 10 years				1
Total			$	28

Realized gains and losses, which were determined on a specific identification basis, from sales of Duke Energy Indiana's available-for-sale securities were insignificant for each of the three and nine months ended September 30, 2013 and 2012.

Variable_Interest_Entities

Variable Interest Entities	9 Months Ended
Variable Interest Entities	Sep. 30, 2013
Variable Interest Entities [Abstract]	'
Variable Interest Entities	'
	11. VARIABLE INTEREST ENTITIES
	A VIE is an entity that is evaluated for consolidation using more than a simple analysis of voting control. The analysis to determine whether an entity is a VIE considers contracts with an entity, credit support for an entity, the adequacy of the equity investment of an entity, and the relationship of voting power to the amount of equity invested in an entity. This analysis is performed either upon the creation of a legal entity or upon the occurrence of an event requiring reevaluation, such as a significant change in an entity's assets or activities. A qualitative analysis of control determines the party that consolidates a VIE. This assessment is based on (i) what party has the power to direct the most significant activities of the VIE that impact its economic performance, and (ii) what party has rights to receive benefits or is obligated to absorb losses that are significant to the VIE. The analysis of the party that consolidates a VIE is a continual reassessment.
	CONSOLIDATED VIEs
	The table below shows VIEs Duke Energy and Duke Energy Carolinas consolidate and how these entities impact Duke Energy's and Duke Energy Carolinas' respective Condensed Consolidated Balance Sheets.
	Other than the discussion below related to CRC, no financial support was provided to any of the consolidated VIEs during the three or nine months ended September 30, 2013 and the year ended December 31, 2012, or is expected to be provided in the future, that was not previously contractually required.

				30-Sep-13
	(in millions)			DERF^(a)			CRC			CinCapV		Renewables				Other			Total
	ASSETS
	Current Assets
	Restricted receivables of variable interest entities				703			527			17			11			―			1,258
	Other				―			―			5			199			2			206
	Investments and Other Assets
	Intangibles, net				―			―			―			11			―			11
	Restricted other assets of variable interest entities				―			―			40			12			―			52
	Other				―			―			12			4			3			19
	Property, Plant and Equipment
	Property, Plant and Equipment, Cost				―			―			―			1,663			16			1,679
	Accumulated depreciation and amortization				―			―			―			-146			-5			-151
	Regulatory Assets and Deferred Debits
	Other				―			―			―			34			―			34
		Total Assets			703			527			74			1,788			16			3,108
	LIABILITIES AND EQUITY
	Current Liabilities
	Accounts payable				―			―			―			3			―			3
	Non-recourse notes payable of variable interest entities				―			325			―			―			―			325
	Taxes accrued				―			―			―			12			―			12
	Current maturities of long-term debt				―			―			14			62			―			76
	Other				―			―			5			26			―			31
	Non-recourse Long-term Debt of variable interest entities				300			―			37			928			―			1,265
	Deferred income taxes				―			―			―			255			―			255
	Asset retirement obligations				―			―			―			25			―			25
	Other				―			―			12			102			―			114
		Total Liabilities			300			325			68			1,413			―			2,106
	Net Assets of Consolidated Variable Interest Entities			$	403		$	202		$	6		$	375		$	16		$	1,002

	(a)	Duke Energy Receivables Finance Company, LLC (DERF) is a wholly owned limited liability company of Duke Energy Carolinas.


				31-Dec-12
	(in millions)			DERF			CRC			CinCapV		Renewables				Other			Total
	ASSETS
	Current Assets
	Restricted receivables of variable interest entities			$	637		$	534		$	15		$	16		$	-1		$	1,201
	Other				―			―			4			133			2			139
	Investments and Other Assets
	Intangibles, net				―			―			―			12			―			12
	Restricted other assets of variable interest entities				―			―			52			2			―			54
	Other				―			―			10			―			2			12
	Property, Plant and Equipment
	Property, Plant and Equipment, Cost				―			―			―			1,543			15			1,558
	Accumulated depreciation and amortization				―			―			―			-98			-5			-103
	Regulatory Assets and Deferred Debits
	Other				―			―			―			40			―			40
		Total Assets			637			534			81			1,648			13			2,913
	LIABILITIES AND EQUITY
	Current Liabilities
	Accounts payable				―			―			―			1			―			1
	Non-recourse notes payable of variable interest entities				―			312			―			―			―			312
	Taxes accrued				―			―			―			62			―			62
	Current maturities of long-term debt				―			―			13			459			―			472
	Other				―			―			4			25			―			29
	Non-recourse Long-term Debt of variable interest entities				300			―			48			504			―			852
Deferred income taxes				―			―			―			154			―			154
Asset retirement obligations				―			―			―			23			―			23
Other				―			―			10			39			―			49
	Total Liabilities			300			312			75			1,267			―			1,954
Net Assets of Consolidated Variable Interest Entities			$	337		$	222		$	6		$	381		$	13		$	959

DERF
Duke Energy Carolinas securitizes certain accounts receivable through DERF, a bankruptcy remote, special purpose subsidiary. DERF has a separate legal existence from its parent, and its assets are not intended to be generally available to creditors of Duke Energy Carolinas. On a daily basis Duke Energy Carolinas sells certain accounts receivable, arising from the sale of electricity and/or related services, to DERF. DERF utilizes a $400 million secured credit facility with a commercial paper conduit to fund purchases of accounts receivable. The facility expires in October 2016. Duke Energy Carolinas services the receivables (collects and applies cash to the appropriate receivables). Duke Energy Carolinas' borrowing under the credit facility is limited to the amount of qualified receivables sold. The amount of receivables sold has been and is expected to be in excess of the amount borrowed. The debt is classified as long-term since the facility has an expiration date of greater than one year from the balance sheet date.
The securitization transaction was not structured to meet the criteria for sale accounting treatment under the accounting guidance for transfers and servicing financial assets and, accordingly, is reflected as a secured borrowing in the Consolidated Balance Sheets. The obligations of DERF under the facility are non-recourse to Duke Energy Carolinas. Duke Energy and its subsidiaries have no requirement to provide liquidity, purchase assets of DERF, or guarantee performance. DERF is considered a VIE because the equity capitalization is insufficient to support its operations. In addition, the most significant activity that impacts the economic performance of DERF relates to decisions made with respect to management of delinquent receivables. Duke Energy Carolinas consolidates DERF since it makes those decisions.
CRC
CRC was formed to secure low cost financing for Duke Energy Ohio and Duke Energy Indiana. Duke Energy Ohio and Duke Energy Indiana sell on a revolving basis at a discount, nearly all of their customer accounts receivable and related collections to CRC. The receivables sold are selected to avoid any significant concentration of credit risk and exclude delinquent receivables. Receivables sold are securitized by CRC through a facility managed by two unrelated third parties and are used as collateral for commercial paper issued by the unrelated third parties. These loans provide the cash portion of proceeds paid by CRC to Duke Energy Ohio and Duke Energy Indiana. Proceeds obtained by Duke Energy Ohio and Duke Energy Indiana from sales of receivables are cash and a subordinated note from CRC. The subordinated note represents a retained interest in the sold receivables and is typically 25 percent of total proceeds. Amounts borrowed by CRC against these receivables is non-recourse to the general credit of Duke Energy. Cash collections from the accounts receivable sold are the sole source of funds to satisfy the related debt obligation. Borrowing is limited to approximately 75 percent of the transferred receivables. Losses on collection in excess of the discount are first absorbed by the equity of CRC and next by subordinated retained interests held by Duke Energy Ohio and Duke Energy Indiana. The discount reflects interest expense plus an allowance for bad debts net of a servicing fee charged by Duke Energy Ohio and Duke Energy Indiana. Duke Energy Ohio and Duke Energy Indiana service the receivables (collect and apply cash to the appropriate receivables). Depending on experience with collections, additional equity infusions to CRC may be required by Duke Energy to maintain a minimum equity balance of $3 million. There were no infusions to CRC during the three or nine months ended September 30, 2013 and 2012. Amounts borrowed fluctuate based on the amounts of receivables sold. The debt is classified as short term because the facility has an expiration date of less than one year from the balance sheet date. The current expiration date is November 2013. CRC is considered a VIE because (i) equity capitalization is insufficient to support its operations, (ii) power to direct the most significant activities that impact economic performance of the entity are not performed by the equity holder, Cinergy Corp. (Cinergy), and (iii) deficiencies in net worth of CRC are not funded by Cinergy, but by Duke Energy. The most significant activity of CRC relates to the decisions made with respect to the management of delinquent receivables. Thus, Duke Energy consolidates CRC. Duke Energy Ohio and Duke Energy Indiana do not consolidate CRC.
CinCap V
CinCap V was created to finance and execute a power sale agreement with Central Maine Power Company for approximately 35 MW of capacity and energy. This agreement expires in 2016. CinCap V is considered a VIE because the equity capitalization is insufficient to support its operations. Duke Energy consolidates CinCap V as it has power to direct the most significant activities that impact economic performance of the entity, which are the decisions to hedge and finance the power sales agreement.
Renewables
Certain of Duke Energy's renewable energy facilities are VIEs due to power purchase agreements with terms that approximate the expected life of the projects. These fixed price agreements effectively transfer commodity price risk to the buyer of the power. Certain other of Duke Energy's renewable energy facilities are VIEs due to Duke Energy issuing debt service reserve guarantees and operations and maintenance reserve guarantees in support of debt financings. The most significant activities that impact the economic performance of these renewable energy facilities were decisions associated with siting, negotiating purchase power agreements, engineering, procurement and construction, and decisions associated with ongoing operations and maintenance related activities. As all of these decisions were made solely by Duke Energy ,Duke Energy has consolidated these entities since inception.
Debt held by these renewable energy facilities is non-recourse to the general credit of Duke Energy. Duke Energy and its subsidiaries have no requirement to provide liquidity or purchase the assets of these renewable energy facilities. Duke Energy does not guarantee performance except for an immaterial multi-purpose letter of credit and various immaterial debt service reserve and operations and maintenance reserve guarantees. Assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders.
NON-CONSOLIDATED VIEs
The tables below show VIEs the Duke Energy Registrants do not consolidate and how these entities impact the Duke Energy Registrants' respective Condensed Consolidated Balance Sheets. As discussed above, while Duke Energy consolidated CRC, Duke Energy Ohio and Duke Energy Indiana do not consolidate CRC as they are not the primary beneficiary.

			30-Sep-13
				Duke Energy											Duke Energy Ohio			Duke Energy Indiana
(in millions)			DukeNet		Renewables				Other			Total			Duke Energy Ohio			Duke Energy Indiana
Receivables			$	―		$	―		$	―		$	―		$	75		$	114
Investments in equity method unconsolidated affiliates				113			152			25			290			―			―
Intangibles, net				―			―			100			100			98			―
Investments and other assets				―			―			4			4			―			―
	Total assets			113			152			129			394			173			114
Other current liabilities				―			―			2			2			―			―
Deferred credits and other liabilities				―			―			15			15			―			―
	Total liabilities			―			―			17			17			―			―
Net assets			$	113		$	152		$	112		$	377		$	173		$	114


			31-Dec-12
			Duke Energy															Duke Energy Ohio			Duke Energy Indiana
(in millions)			DukeNet		Renewables				FPC Capital I Trust^(a)			Other			Total			Duke Energy Ohio			Duke Energy Indiana
Receivables			$	―		$	―		$	―		$	―		$	―		$	97		$	116
Investments in equity method unconsolidated affiliates				118			147			―			27			292			―			―
Intangibles, net				―			―			―			104			104			104			―
Investments and other assets				―			―			9			2			11			―			―
	Total assets			118			147			9			133			407			201			116
Other current liabilities				―			―			―			3			3			―			―
Deferred credits and other liabilities				―			―			319			17			336			―			―
	Total liabilities			―			―			319			20			339			―			―
Net assets (liabilities)			$	118		$	147		$	-310		$	113		$	68		$	201		$	116

(a)	The entire balance of Investments and other assets and $274 million of the Deferred credits and other liabilities balance applies to Progress Energy.

No financial support not previously contractually required was provided to any of the unconsolidated VIEs during the three or nine months ended September 30, 2013 and 2012, or is expected to be provided in the future. The Duke Energy Registrants are not aware of any situations where the maximum exposure to loss significantly exceeds the carrying values shown above except for the power purchase agreement with the Ohio Valley Electric Corporation (OVEC), which is discussed below, and various guarantees, reflected in the table above as Deferred credits and other liabilities.
DukeNet
Duke Energy owns a 50 percent interest in DukeNet. DukeNet has a 5-year, $150 million senior secured credit facility with a syndicate of ten external financial institutions. This credit facility is non-recourse to Duke Energy. DukeNet is considered a VIE because it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. Duke Energy has no requirement to provide liquidity, purchase the assets of DukeNet, or guarantee performance. The most significant activities that impact DukeNet's economic performance relate to its business development and fiber optic capacity marketing and management activities. The power to direct these activities is jointly and equally shared by Duke Energy and the other joint venture partner. Accordingly, DukeNet is a non-consolidated VIE and is accounted for as an equity method investment.
Unless consent by Duke Energy is given, Duke Energy and its subsidiaries have no requirement to provide liquidity, purchase the assets of DukeNet, or guarantee performance.
On October 4, 2013, Duke Energy announced that it will sell its interest in DukeNet. Refer to Note 2 for more information.
Renewables
Duke Energy has investments in various renewable energy project entities. Some of these entities are VIEs due to power purchase agreements with terms that approximate the expected life of the project. These fixed price agreements effectively transfer commodity price risk to the buyer of the power. Duke Energy does not consolidate these VIEs because power to direct and control key activities is shared jointly by Duke Energy and other owners. Duke Energy accounts for these investments under the equity method of accounting.
FPC Capital I Trust
At December 31, 2012, Progress Energy had variable interests in the FPC Capital I Trust (the Trust). The Trust, a finance subsidiary, was established in 1999 for the sole purpose of issuing $300 million of 7.10% QUIPS due 2039, and used proceeds thereof to purchase $300 million of 7.10% Junior Subordinated Deferrable Interest Notes due 2039 from Florida Progress Funding Corporation (Funding Corp.). Funding Corp. is a wholly owned subsidiary of Progress Energy. The Trust had no other operations and its sole assets were subordinated notes and related guarantees. Funding Corp. was formed for the sole purpose of providing financing to Duke Energy Florida. Funding Corp. did not engage in business activities other than such financing and had no independent operations. Progress Energy guaranteed the payments of all distributions required by the Trust. On February 1, 2013, Duke Energy redeemed the $300 million of 7.10% QUIPS and subsequently terminated the Trust.
Other
Duke Energy has investments in various other entities that are not consolidated VIEs. The most significant of these investments is Duke Energy Ohio's 9 percent ownership interest in OVEC. Through its ownership interest in OVEC, Duke Energy Ohio has a contractual arrangement to buy power from OVEC's power plants through June 2040. Proceeds from the sale of power by OVEC to its power purchase agreement counterparties are designed to be sufficient to meet its operating expenses, fixed costs, debt amortization and, interest expense, as well as earn a return on equity. Accordingly, the value of this contract is subject to variability due to fluctuations in power prices and changes in OVEC's costs of business, including costs associated with its 2,256 MW of coal-fired generation capacity. As discussed in Note 5, proposed environmental rulemaking could increase the costs of OVEC, which would be passed through to Duke Energy Ohio. The initial carrying value of this contract was recorded as an intangible asset when Duke Energy acquired Cinergy in April 2006. In addition, Duke Energy has guaranteed performance of certain entities in which it no longer has an equity interest.
CRC
As discussed above, CRC is consolidated only by Duke Energy. Accordingly, the retained interest in the sold receivables recorded on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana are eliminated in consolidation at Duke Energy.
Proceeds obtained from sales of receivables are largely cash but do include a subordinated note from CRC. The subordinated note is a retained interest and is classified within Receivables in Duke Energy Ohio's and Duke Energy Indiana's Condensed Consolidated Balance Sheets. Retained interests reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana approximate fair value.
Carrying values of retained interests are determined by allocating carrying value of the receivables between assets sold and interests retained based on relative fair value. The allocated basis of the subordinated notes are not materially different than their face value because (i) the receivables generally turnover in less than two months, (ii) credit losses are reasonably predictable due to the broad customer base and lack of significant concentration, and (iii) the equity in CRC is subordinate to all retained interests and thus would absorb losses first. The hypothetical effect on fair value of the retained interests assuming both a 10 percent and a 20 percent unfavorable variation in credit losses or discount rates is not material due to the short turnover of receivables and historically low credit loss history. Interest accrues to Duke Energy Ohio and Duke Energy Indiana on retained interests using the acceptable yield method. This method generally approximates the stated rate on the notes since the allocated basis and face value are nearly equivalent. An impairment charge is recorded against the carrying value of both retained interests and purchased beneficial interest whenever it is determined an other-than-temporary impairment has occurred. Key assumptions used in estimating fair value in 2013 and 2012 are detailed in the following table.

			Duke Energy Ohio						Duke Energy Indiana
			2013			2012			2013			2012
Anticipated credit loss ratio			0.6	%		0.7	%		0.3	%		0.3	%
Discount rate			1.2	%		1.2	%		1.2	%		1.2	%
Receivable turnover rate			12.8	%		12.7	%		10.3	%		10.2	%

The following table shows the gross and net receivables sold.

		Duke Energy Ohio							Duke Energy Indiana
(in millions)		30-Sep-13			31-Dec-12				30-Sep-13			31-Dec-12
Receivables sold			$	235		$	282			$	332		$	289
Less: Retained interests				75			97				114			116
Net receivables sold			$	160		$	185			$	218		$	173

The following tables show sales and cash flows related to receivables sold.

		Duke Energy Ohio							Duke Energy Indiana
		Three Months Ended September 30,							Three Months Ended September 30,
(in millions)			2013			2012				2013			2012
Sales
Receivables sold			$	514		$	518			$	765		$	711
Loss recognized on sale				3			3				2			3
Cash flows
Cash proceeds from receivables sold				518			531				758			733
Collection fees received				―			―				―			―
Return received on retained interests				1			1				2			2



		Duke Energy Ohio							Duke Energy Indiana
		Nine Months Ended September 30,							Nine Months Ended September 30,
(in millions)		2013				2012			2013				2012
Sales
Receivables sold			$	1,664		$	1,618			$	2,214		$	2,118
Loss recognized on sale				9			10				8			9
Cash flows
Cash proceeds from receivables sold				1,674			1,651				2,204			2,130
Collection fees received				1			1				1			1
Return received on retained interests				4			4				5			5

Cash flows from sales of receivables are reflected within Operating Activities on Duke Energy Ohio's and Duke Energy Indiana's Condensed Consolidated Statements of Cash Flows.
Collection fees received in connection with servicing transferred accounts receivable are included in Operation, maintenance and other on Duke Energy Ohio's and Duke Energy Indiana's Condensed Consolidated Statements of Operations and Comprehensive Income. The loss recognized on sales of receivables is calculated monthly by multiplying receivables sold during the month by the required discount. The required discount is derived monthly utilizing a three-year weighted average formula that considers charge-off history, late charge history, and turnover history on the sold receivables, as well as a component for the time value of money. The discount rate, or component for the time value of money, is calculated monthly by summing the prior month-end LIBOR plus a fixed rate of 1.00 percent.

Earnings_Per_Share

Earnings Per Share	9 Months Ended
Earnings Per Share	Sep. 30, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share	'
	12. EARNINGS PER COMMON SHARE (EPS)
	Basic Earnings Per Share (EPS) is computed by dividing net income attributable to Duke Energy common shareholders, adjusted for distributed and undistributed earnings allocated to participating securities, by the weighted-average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income attributable to Duke Energy common shareholders, as adjusted for distributed and undistributed earnings allocated to participating securities, by the diluted weighted-average number of common shares outstanding during the period. Diluted EPS reflects the potential dilution that could occur if securities or other agreements to issue common stock, such as stock options, phantom shares and stock-based performance unit awards were exercised or settled.
	The following table presents Duke Energy's basic and diluted EPS calculations and reconciles the weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding.

	(In millions, except per-share amounts)	Income		Average Shares			EPS
	Three Months Ended September 30, 2013
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	989		706	$	1.4
	Three Months Ended September 30, 2012
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	589		699	$	0.84


	(In millions, except per-share amounts)	Income		Average Shares			EPS
	Nine Months Ended September 30, 2013
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	1,959		706	$	2.78
	Nine Months Ended September 30, 2012
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	1,326		531	$	2.5

	As of September 30, 2013 and 2012, 2 million and 1 million, respectively, of stock options and performance and unvested stock awards were not included in the dilutive securities calculation in the above table because either the option exercise prices were greater than the average market price of the common shares during those periods, or performance measures related to the awards had not yet been met.

StockBased_Compensation

Stock-Based Compensation	9 Months Ended
Stock-Based Compensation	Sep. 30, 2013
Stock-Based Compensation [Abstract]	'
Stock-Based Compensation	'
	13. STOCK-BASED COMPENSATION
	For employee awards, equity classified stock-based compensation cost is measured at the service inception date or the grant date, based on the estimated achievement of certain performance metrics or the fair value of the award, and is recognized as expense or capitalized as a component of property, plant and equipment over the requisite service period.
	Duke Energy recorded pretax stock-based compensation expense as follows.

		Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)			2013		2012			2013		2012
	Stock options		$	―	$	―		$	2	$	2
	Restricted stock unit awards			10		16			36		30
	Performance awards			7		16			25		19
	Total		$	17	$	32		$	63	$	51
	Tax benefit associated with stock-based compensation expense		$	6	$	13		$	24	$	20
	Stock-based compensation costs capitalized			1		―			3		1

Employee_Benefit_Obligations

Employee Benefit Obligations	9 Months Ended
Employee Benefit Obligations	Sep. 30, 2013
Employee Benefit Plans [Abstract]	'
Employee Benefit Obligations	'
	14. EMPLOYEE BENEFIT PLANS
	DEFINED BENEFIT RETIREMENT PLANS
	Duke Energy and its subsidiaries (including legacy Progress Energy and Cinergy businesses) maintain qualified, non-contributory defined benefit retirement plans. Duke Energy also maintains non-qualified, non-contributory defined benefit retirement plans, which cover certain executives. The Subsidiary Registrants participate in these plans.
	In September 2013, Duke Energy adopted a de-risking investment strategy for its pension plan assets. As the funded status of the Duke Energy and Progress Energy pension plans increase, over time the allocation to return-seeking assets will be reduced and the allocation to fixed-income assets will be increased to better manage Duke Energy's pension liability and reduce funded status volatility. Based on the current funded status of the plans, the asset allocation for the Duke Energy pension plans has been adjusted to 60 percent fixed-income assets and 40 percent return-seeking assets and the asset allocation for the Progress Energy pension plans has been adjusted to 55 percent fixed-income assets and 45 percent return-seeking assets.
	Duke Energy has made contributions directly to pension plan assets during the nine months ended September 30, 2013 of $27 million, all of which relates to Duke Energy Florida. Future amounts contributed may be impacted by recently enacted legislation as well as other factors.
	Net periodic benefit costs disclosed in the tables below for pension and other post-retirement benefit plans represent the cost of the respective benefit plan for the periods presented. However, portions of the net periodic benefit costs disclosed in the tables below have been capitalized as a component of property, plant and equipment.
	Amounts presented in the tables below for the Subsidiary Registrants represent allocated amounts of pension and other post-retirement benefit cost for employees of the Subsidiary Registrants. Additionally, the Subsidiary Registrants are allocated their proportionate share of pension and post-retirement benefit cost for employees of Duke Energy's shared services affiliates that provide support to the Subsidiary Registrants. These allocated amounts are included in the governance and shared service costs discussed in Note 17.
	QUALIFIED PENSION PLANS

	The following tables include the components of net periodic pension costs for qualified pension plans.

			Three Months Ended September 30, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	41		$	12		$	15		$	6		$	8		$	1		$	2
	Interest cost on projected benefit obligation			80			20			29			13			13			5			7
	Expected return on plan assets			-137			-37			-50			-24			-21			-7			-11
	Amortization of prior service credit			-2			-2			-1			-1			-1			―			―
	Amortization of actuarial loss			61			15			26			11			12			3			6
	Other			2			1			―			1			―			―			1
	Net periodic pension costs^(a)(b)		$	45		$	9		$	19		$	6		$	11		$	2		$	5

			Three Months Ended September 30, 2012
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	39		$	9		$	16		$	6		$	8		$	2		$	2
	Interest cost on projected benefit obligation			94			23			32			15			14			7			8
	Expected return on plan assets			-142			-36			-48			-25			-21			-11			-12
	Amortization of prior service cost			3			―			2			2			―			―			1
	Amortization of actuarial loss			47			11			24			9			13			2			3
	Other			2			―			1			1			―			―			―
	Net periodic pension costs^(a)(b)		$	43		$	7		$	27		$	8		$	14		$	―		$	2

	(a)	Duke Energy amounts exclude $3 million for each of the three months ended September 30, 2013 and 2012, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.
	(b)	Duke Energy Ohio amounts exclude $1 million and $2 million for the three months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.


			Nine Months Ended September 30, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	125		$	37		$	45		$	17		$	23		$	4		$	8
	Interest cost on projected benefit obligation			240			60			87			38			40			16			21
	Expected return on plan assets			-411			-111			-149			-71			-65			-22			-33
	Amortization of prior service credit			-8			-5			-3			-1			-2			―			―
	Amortization of actuarial loss			183			45			76			34			37			9			17
	Other			5			2			1			1			―			―			1
	Net periodic pension costs^(a)(b)		$	134		$	28		$	57		$	18		$	33		$	7		$	14

			Nine Months Ended September 30, 2012
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	84		$	26		$	47		$	19		$	22		$	5		$	7
	Interest cost on projected benefit obligation			214			68			95			43			42			23			23
	Expected return on plan assets			-330			-109			-141			-72			-61			-33			-35
	Amortization of prior service cost			6			1			7			6			―			―			2
	Amortization of actuarial loss			96			34			69			28			36			7			10
	Other			4			1			1			1			―			―			―
	Net periodic pension costs^(a)(b)		$	74		$	21		$	78		$	25		$	39		$	2		$	7

	(a)	Duke Energy amounts exclude $9 million and $10 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.
	(b)	Duke Energy Ohio amounts exclude $4 million and $5 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.

	NON-QUALIFIED PENSION PLANS

	The following tables include the components of net periodic pension costs for non-qualified pension plans for registrants with non-qualified pension costs.

			Three Months Ended September 30, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
Service cost		$	1		$	―		$	1		$	1		$	―
Interest cost on projected benefit obligation			3			―			1			―			―
Amortization of actuarial loss			1			―			1			1			1
Net periodic pension costs		$	5		$	―		$	3		$	2		$	1

		Three Months Ended September 30, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
Interest cost on projected benefit obligation		$	5		$	―		$	2		$	1		$	1
Amortization of actuarial loss			1			―			1			―			―
Net periodic pension costs		$	6		$	―		$	3		$	1		$	1


		Nine Months Ended September 30, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
Service cost		$	2		$	―		$	1		$	1		$	―
Interest cost on projected benefit obligation			10			1			5			1			1
Amortization of actuarial loss			4			―			3			1			1
Amortization of prior service credit			-1			―			-1			―			―
Net periodic pension costs		$	15		$	1		$	8		$	3		$	2

		Nine Months Ended September 30, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
Service cost		$	1		$	―		$	1		$	1		$	―
Interest cost on projected benefit obligation			8			1			6			1			2
Amortization of actuarial loss			2			―			3			1			―
Amortization of prior service cost			1			―			―			―			―
Net periodic pension costs		$	12		$	1		$	10		$	3		$	2

OTHER POST-RETIREMENT BENEFIT PLANS
Duke Energy and most of its subsidiaries provide some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. The Subsidiary Registrants participate in these plans. Employees are eligible for these benefits if they have met age and service requirements at retirement, as defined in the plans. The health care benefits include medical coverage, dental coverage, vision, and prescription drug coverage and are subject to certain limitations, such as deductibles and co-payments.
Duke Energy uses a December 31 measurement date for its other post-retirement benefit plan assets and obligations. However, due to the impact of certain changes in Legacy Progress Energy health care benefits announced in September 2013, Duke Energy remeasured its Legacy Progress Energy other post-retirement benefit plan obligation as of September 30, 2013. There are no plan assets associated with the Legacy Progress Energy other post-retirement benefit plan. The discount rate used for the remeasurement was 4.7%. The health care cost trend rate of 8.5% reduces to 5.0% over eight years. The mortality tables were updated to account for mortality improvement. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2012.
The following table summarizes the reduction in accumulated other post-retirement benefit obligation recorded in September 2013 by each of the Duke Energy Registrants as a result of the remeasurement. The offsetting amounts for these items were recorded as decreases to regulatory assets.

(in millions)
Duke Energy			$	551
Progress Energy				551
Duke Energy Progress				382
Duke Energy Florida				103

The following tables include the components of net periodic other post-retirement benefit costs.

		Three Months Ended September 30, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	7		$	1		$	6		$	3		$	2		$	―		$	1
Interest cost on accumulated post-retirement benefit obligation			19			3			12			7			5			―			1
Expected return on plan assets			-4			-2			―			―			―			―			-1
Amortization of prior service credit			-3			-2			―			―			―			―			―
Amortization of actuarial loss			13			―			13			8			4			―			1
Net periodic other post-retirement benefit costs^(a)		$	32		$	―		$	31		$	18		$	11		$	―		$	2

		Three Months Ended September 30, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	7		$	1		$	5		$	2		$	2		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation			19			4			11			6			4			1			1
Expected return on plan assets			-4			-3			―			―			―			-1			―
Amortization of prior service credit			-2			-2			―			―			―			―			―
Amortization of net transition liability			3			2			1			―			1			―			―
Amortization of actuarial loss (gain)			8			1			10			6			3			-1			―
Special termination charge			9			1			5			2			1			―			―
Net periodic other post-retirement benefit costs^(a)		$	40		$	4		$	32		$	16		$	11		$	―		$	2

(a)	Duke Energy amounts exclude $2 million and $3 million for the three months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.


		Nine Months Ended September 30, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	21		$	2		$	17		$	9		$	6		$	―		$	1
Interest cost on accumulated post-retirement benefit obligation			55			9			35			19			13			1			4
Expected return on plan assets			-11			-7			―			―			―			―			-1
Amortization of prior service credit			-9			-6			-1			-1			―			―			―
Amortization of actuarial loss (gain)			39			2			42			26			12			-1			1
Net periodic other post-retirement benefit costs^(a)(b)		$	95		$	―		$	93		$	53		$	31		$	―		$	5

		Nine Months Ended September 30, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	10		$	2		$	12		$	6		$	5		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation			36			12			32			17			13			2			5
Expected return on plan assets			-12			-8			-1			―			-1			-1			-1
Amortization of prior service credit			-6			-4			―			―			―			―			1
Amortization of net transition liability			7			5			3			―			2			―			―
Amortization of actuarial loss (gain)			5			2			25			14			9			-2			-1
Special termination charge			9			1			5			2			1			―			―
Net periodic other post-retirement benefit costs^(a)(b)		$	49		$	10		$	76		$	39		$	29		$	―		$	5

(a)	Duke Energy amounts exclude $6 million and $7 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.
(b)	Duke Energy Ohio amounts exclude $1 million for each of the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.

EMPLOYEE SAVINGS PLANS
Duke Energy and Progress Energy sponsor employee savings plans that cover substantially all U.S. employees. The Subsidiary Registrants participate in these plans. Most employees participate in a matching contribution formula where Duke Energy provides a matching contribution generally equal to 100 percent of employee before-tax and Roth 401(k) contributions, and, as applicable, after-tax contributions, of up to 6 percent of eligible pay per pay period. Dividends on Duke Energy shares held by the savings plans are charged to retained earnings when declared and shares held in the plans are considered outstanding in the calculation of basic and diluted EPS.
Pretax employer matching contributions expensed were as follows.

		Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)				2013			2012				2013			2012
Duke Energy			$	30		$	30			$	101		$	77
Duke Energy Carolinas				10			8				34			28
Progress Energy				12			12				34			35
Duke Energy Progress				7			7				19			18
Duke Energy Florida				4			4				11			11
Duke Energy Ohio				―			1				2			3
Duke Energy Indiana				2			2				5			5

Severance

Severance	9 Months Ended
Severance	Sep. 30, 2013
Severance [Abstract]	'
Severance	'
	15. SEVERANCE
	In conjunction with the merger with Progress Energy, in November 2011, Duke Energy and Progress Energy offered a voluntary severance plan to certain eligible employees. As this was a voluntary severance plan, all severance benefits offered under this plan are considered special termination benefits under U.S. GAAP. Special termination benefits are measured upon employee acceptance and recorded immediately absent any significant retention period. If a significant retention period exists, the cost of the special termination benefits are recorded ratably over the retention period. Approximately 1,100 employees from Duke Energy and Progress Energy requested severance during the voluntary window, which closed on November 30, 2011. The estimated amount of future severance expense associated with this voluntary plan and other severance benefits through 2014 are not material.
	Additionally, in the third quarter of 2012, a voluntary severance plan was offered to certain unionized employees of Duke Energy Ohio. Approximately 75 employees accepted the termination benefits during the voluntary window, which closed on October 8, 2012. The expense associated with this plan was not material.
	In conjunction with the retirement of Crystal River Unit 3, severance benefits will be made available to certain eligible impacted unionized and non-unionized employees, to the extent that those employees do not find job opportunities at other locations. Approximately 600 employees worked at Crystal River Unit 3. For the nine months ended September 30, 2013, Duke Energy Florida deferred $26 million of severance costs as a regulatory asset. Severance costs expected to be accrued over the remaining retention period for employees identified to have a significant retention period is not material. However, these employees maintain the ability to accept job opportunities at other Duke Energy locations, which would result in severance not being paid. If a significant amount of these individuals redeploy within Duke Energy, the final severance benefits paid under the plan may be less than what has been accrued to date. Refer to Note 4 for further discussion regarding Crystal River Unit 3.
	Amounts included in the table below represent direct and allocated severance and related expense recorded by the Duke Energy Registrants, and are recorded in Operation, maintenance, and other within Operating Expenses on the Condensed Consolidated Statements of Operations.

			Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)				2013			2012				2013			2012
	Duke Energy			$	5		$	146			$	30		$	146
	Duke Energy Carolinas				—			48				7			48
	Progress Energy				4			66				17			66
	Duke Energy Progress				3			42				12			42
	Duke Energy Florida				1			24				5			24
	Duke Energy Ohio				—			15				2			15
	Duke Energy Indiana				—			13				2			13

	Amounts included in the table below represent the severance liability for past and ongoing severance plans. Amounts for Subsidiary Registrants do not include allocated expense or associated cash payments. Amounts for Duke Energy Ohio and Duke Energy Indiana are not material.

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
	Balance at December 31, 2012		$	135		$	12		$	43		$	23		$	6
	Provision / Adjustments^(a)			41			2			45			7			30
	Cash Reductions			-114			-12			-42			-17			-13
	Balance at September 30, 2013		$	62		$	2		$	46		$	13		$	23

	(a)	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Income_Taxes_and_Other_Taxes

Income Taxes and Other Taxes	9 Months Ended
Income Taxes and Other Taxes	Sep. 30, 2013
Income Taxes And Other Taxes [Abstract]	'
Income Taxes And Other Taxes	'
	16. INCOME TAXES AND OTHER TAXES
	INCOME TAXES
	Duke Energy and its subsidiaries file income tax returns in the U.S. with federal and various state governmental authorities, and in certain foreign jurisdictions. The taxable income of Duke Energy and its subsidiaries is reflected in Duke Energy's U.S. federal and state income tax returns. These subsidiaries have a tax sharing agreement with Duke Energy where the separate return method is used to allocate tax expenses and benefits to the subsidiaries whose investments or results of operations provide these tax expenses and benefits. The accounting for income taxes essentially represents the income taxes that each of these subsidiaries would incur if it were a separate company filing its own tax return as a C-Corporation.
	The following table includes information regarding the Duke Energy Registrants' unrecognized tax benefits.

			Nine Months Ended September 30, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Unrecognized tax benefits - January 1		$	540		$	271		$	131		$	67		$	44	$	36	$	32
	Gross decreases - tax positions in prior periods			-230			-96			-85			-45			-37		-36		-31
	Settlements			-66			-4			―			―			―		―		―
		Total changes		-296			-100			-85			-45			-37		-36		-31
	Unrecognized tax benefits - September 30^(a)		$	244		$	171		$	46		$	22		$	7	$	―	$	1

	(a)	The Duke Energy Registrants do not anticipate a significant increase or decrease in unrecognized tax benefits in the next twelve months.

	Duke Energy and its subsidiaries are no longer subject to U.S. federal examination for years before 2006. The years 2006 and 2007 are in Appeals. The Internal Revenue Service (IRS) is currently auditing the federal income tax returns for years 2008 and 2011. With few exceptions, Duke Energy and its subsidiaries are no longer subject to state, local or non-U.S. income tax examinations by tax authorities for years before 1999.
	The effective tax rates for each of the Duke Energy Registrants are included in the following table.

			Three Months Ended September 30,							Nine Months Ended September 30,
				2013			2012				2013			2012
	Duke Energy			31.5	%		29.4	%			32.6	%		29.6	%
	Duke Energy Carolinas			37.9	%		34.2	%			37.5	%		35.8	%
	Progress Energy			38.8	%		32.8	%			38.1	%		34.7	%
	Duke Energy Progress			35.7	%		31.9	%			37.3	%		31.6	%
	Duke Energy Florida			40	%		35.9	%			40	%		36.9	%
	Duke Energy Ohio			42.9	%		45.2	%			40.4	%		38.9	%
	Duke Energy Indiana			36.6	%		55.1	%			37.2	%		47.7	%

	The increase in the effective tax rate for Duke Energy for the nine months ended September 30, 2013, is primarily due to lower pretax income in 2012 due to the Edwardsport IGCC project impairment, Progress Energy results of operations included in 2013 compared to post-merger inclusion in 2012, impact of lower AFUDC equity in 2013, and a reduction of foreign deferred taxes in 2012 due to changes in foreign tax rates.
	The increase in the effective tax rate for Duke Energy Carolinas for the three months ended September 30, 2013, is primarily due to higher pretax book income and the impact of lower AFUDC equity in 2013.
	The increase in the effective tax rate for Progress Energy for the three and nine months ended September 30, 2013, is primarily due to the charges related to the 2013 Settlement Agreement, the impact of lower AFUDC equity and the Employee Stock Ownership Plan (ESOP) dividend deduction being recorded at Duke Energy in 2013.
	The increase in the effective tax rate for Duke Energy Progress for the three and nine months ended September 30, 2013, is primarily due to the favorable prior-year tax benefit related to the manufacturing deduction and the impact of lower AFUDC equity in 2013.
	The increase in the effective tax rate for Duke Energy Florida for the three and nine months ended September 30, 2013, is primarily due to charges related to the 2013 FPSC settlement agreement, the favorable prior-year tax benefit related to the manufacturing deduction and the impact of lower AFUDC equity in 2013.
	The decrease in the effective tax rate for Duke Energy Indiana for the three and nine months ended September 30, 2013, is primarily due to pretax income in 2013 compared to pretax loss in 2012 related to the Edwardsport IGCC project impairment and the impact of AFUDC equity in 2013 that reduced the tax expense compared to higher AFUDC in 2012, which increased the tax benefit.
	On July 23, 2013, North Carolina House Bill 998 (HB 998) was signed into law. HB 998 reduces the North Carolina corporate income tax rate from a statutory 6.9 percent to 6.0 percent in January 2014 with a further reduction to 5.0 percent in January 2015. Duke Energy recorded a net reduction of approximately $145 million to its North Carolina deferred tax liability in the third quarter of 2013. The significant majority of this deferred tax liability reduction was offset by recording a regulatory liability pending NCUC determination of the disposition of the amounts related to Duke Energy Carolinas and Duke Energy Progress. The impact of HB 998 did not have a significant impact on the financial position, results of operation, or cash flows of Duke Energy, Duke Energy Carolinas, Progress Energy or Duke Energy Progress.
	EXCISE TAXES
	Certain excise taxes levied by state or local governments are collected by the Duke Energy Registrants from their customers. These taxes, which are required to be paid regardless of the Duke Energy Registrants' ability to collect from the customer, are accounted for on a gross basis. When the Duke Energy Registrants act as an agent, and the tax is not required to be remitted if it is not collected from the customer, the taxes are accounted for on a net basis. The Duke Energy Registrants' excise taxes accounted for on a gross basis and recorded as operating revenues in the Condensed Consolidated Statements of Operations are included in the following table.

			Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)				2013			2012				2013			2012
	Duke Energy			$	170		$	178			$	461		$	325
	Duke Energy Carolinas				46			47				124			125
	Progress Energy				89			95				230			241
	Duke Energy Progress				33			33				88			85
	Duke Energy Florida				56			62				142			156
	Duke Energy Ohio				26			26				81			79
	Duke Energy Indiana				9			9				26			25

Related_Party_Transactions

Related Party Transactions	9 Months Ended
Related Party Transactions	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	17. RELATED PARTY TRANSACTIONS
	The Subsidiary Registrants engage in related party transactions, which are generally performed at cost and in accordance with the applicable state and federal commission regulations. Refer to the Condensed Consolidated Balance Sheets of the Subsidiary Registrants for balances due to or due from related parties. Amounts related to transactions with related parties included in the Condensed Consolidated Statements of Operations and Comprehensive Income were as follows.

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

	In addition to the amounts presented above, the Subsidiary Registrants record the impact on net income of other affiliate transactions, including rental of office space, participation in a money pool arrangement, other operational transactions and their proportionate share of certain charged expenses. See Note 6 to the Consolidated Financial Statements in the Annual Report on Form 10-K for more information regarding money pool. The net impact of these transactions was not material for the three and nine months ended September 30, 2013 and 2012 for the Subsidiary Registrants.
	As discussed in Note 11, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an unconsolidated entity formed by a subsidiary of Duke Energy. The proceeds obtained from the sales of receivables are largely cash but do include a subordinated note from CRC for a portion of the purchase price.
	In January 2012, Duke Energy Ohio recorded a non-cash after tax equity transfer of $28 million related to the sale of Vermilion to Duke Energy Indiana. Duke Energy Indiana recorded a non-cash after tax equity transfer of $26 million for the purchase of Vermillion from Duke Energy Ohio. See note 2 for further discussion.
	Duke Energy Commercial Asset Management (DECAM) is a nonregulated, direct subsidiary of Duke Energy Ohio. DECAM conducts business activities, including the execution of commodity transactions, third party vendor and supply contracts and service contracts, for certain of Duke Energy's nonregulated entities. The commodity contracts that DECAM enters either do not qualify as hedges or are accounted for as undesignated contracts. Consequently, mark-to-market impacts of intercompany contracts with, and sales of power to, nonregulated entities are reflected in Duke Energy Ohio's Condensed Consolidated Statements of Operations and Comprehensive Income. These amounts totaled net expense of $7 million and net revenue of $31 million, respectively, for the nine months ended September 30, 2013 and 2012. Because it is not a rated entity, DECAM receives its credit support from Duke Energy or its nonregulated subsidiaries and not the regulated utility operations of Duke Energy Ohio. DECAM meets its funding needs through an intercompany loan agreement from a subsidiary of Duke Energy. DECAM also has the ability to loan money to the subsidiary of Duke Energy. DECAM had an outstanding intercompany loan receivable of $46 million at September 30, 2013 and an outstanding loan payable of $79 million as of December 31, 2012, which were recorded in Notes receivable from affiliated companies and Notes payable to affiliated companies, respectively, on Duke Energy Ohio's Condensed Consolidated Balance Sheets.

New_Accounting_Standards

New Accounting Standards	9 Months Ended
New Accounting Standards	Sep. 30, 2013
New Accounting Standards [Abstract]	'
New Accounting Standards	'
	18. NEW ACCOUNTING STANDARDS
	The following new accounting standards were adopted by the Duke Energy Registrants subsequent to September 30, 2012, and the impact of such adoption, if applicable, has been presented in the accompanying Condensed Consolidated Financial Statements:
	Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 210 — Balance Sheet
	In January 2013, the FASB issued revised accounting guidance to amend the existing disclosure requirements for offsetting financial assets and liabilities to enhance current disclosures, as well as to improve comparability of balance sheets prepared under U.S. GAAP and International Financial Reporting Standards (IFRS). The revised disclosure guidance affects all companies that have financial instruments and derivative instruments that are either offset in the balance sheet (i.e., presented on a net basis) or subject to an enforceable master netting arrangement and/or similar agreement. The revised guidance requires that certain enhanced quantitative and qualitative disclosures be made with respect to a company's netting arrangements and/or rights of setoff associated with its financial instruments and/or derivative instruments including associated collateral. For the Duke Energy Registrants, the revised disclosure guidance was effective on a retrospective basis for interim and annual periods beginning January 1, 2013. Other than additional disclosures, this revised guidance does not impact the Duke Energy Registrants' results of operations, cash flows or financial position.
	ASC 220 — Comprehensive Income
	In February 2013, the FASB amended the existing requirements for presenting comprehensive income in financial statements to improve the reporting of reclassifications out of AOCI. The amendments in the guidance seek to attain that objective by requiring an entity to report the effect of significant reclassifications out of AOCI on the respective line items in net income if the amount being reclassified is required under U.S. GAAP to be reclassified in its entirety to net income. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income in the same reporting period, an entity is required to cross-reference other disclosures required under U.S. GAAP that provide additional detail about those amounts. This would be the case when a portion of the amount reclassified out of AOCI is reclassified to a balance sheet account (for example, property, plant and equipment) instead of directly to income or expense in the same reporting period. For the Duke Energy Registrants, this revised guidance was effective on a prospective basis for interim and annual periods beginning January 1, 2013. This revised guidance does not impact the Duke Energy Registrants' results of operations, cash flows or financial position.
	The following new Accounting Standards Update (ASU) has been issued, but has not yet been adopted by Duke Energy, as of September 30, 2013.
	ASC 830—Foreign Currency Matters.
	In March 2013, the FASB issued revised accounting guidance to resolve the diversity in practice about the release of the cumulative translation adjustment into net income when a parent either sells a part or all of its investment in a foreign entity or no longer holds a controlling financial interest in a subsidiary or group of assets that is a business (other than a sale of in substance real estate) within a foreign entity. In addition, the amendments resolve the diversity in practice for the release of the cumulative translation adjustment involving business combinations achieved in stages by either a Duke investor or a third party acquirer. For the Duke Energy Registrants, the revised accounting guidance is effective on a prospective basis for interim and annual periods beginning January 1, 2014. The revised guidance will impact the timing of the recognition of the cumulative translation adjustment for certain future transactions and therefore, could impact the Duke Energy Registrants' results of operations, cash flows and financial position.

Subsequent_Events

Subsequent Events	9 Months Ended
Subsequent Events	Sep. 30, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	19. SUBSEQUENT EVENTS
	For information on subsequent events related to acquisitions and dispositions, regulatory matters, commitments and contingencies, debt and credit facilities, and risk management, derivatives and hedging activities see Notes 2, 4, 5, 6 and 8, respectively.

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Policy)	9 Months Ended
Organization and Basis of Presentation (Policy)	Sep. 30, 2013
Policy Text Block [Line Items]	'
Organization	'
	NATURE OF OPERATIONS AND BASIS OF CONSOLIDATION
	Duke Energy Corporation (collectively with its subsidiaries, Duke Energy), is an energy company headquartered in Charlotte, North Carolina, subject to regulation by the Federal Energy Regulatory Commission (FERC). Duke Energy operates in the United States (U.S.) and Latin America primarily through its direct and indirect subsidiaries. Duke Energy's subsidiaries include its subsidiary registrants, Duke Energy Carolinas, LLC (Duke Energy Carolinas); Progress Energy, Inc. (Progress Energy); Duke Energy Progress, Inc. (Duke Energy Progress); Duke Energy Florida, Inc. (Duke Energy Florida); Duke Energy Ohio, Inc. (Duke Energy Ohio) and Duke Energy Indiana, Inc. (Duke Energy Indiana). When discussing Duke Energy's consolidated financial information, it necessarily includes the results of its six separate subsidiary registrants (collectively referred to as the Subsidiary Registrants), which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.
	As discussed in the combined Annual Report on Form 10-K for the year ended December 31, 2012, Duke Energy merged with Progress Energy on July 2, 2012. Accordingly, Duke Energy's consolidated financial statements include Progress Energy, Duke Energy Progress and Duke Energy Florida activity beginning July 2, 2012. See Note 2 for additional information regarding the merger.
	The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to Combined Notes. However, none of the registrants makes any representation as to information related solely to Duke Energy or the subsidiaries of Duke Energy other than itself. As discussed further in Note 3, Duke Energy operates three reportable business segments: U.S. Franchised Electric and Gas (USFE&G), Commercial Power and International Energy. The remainder of Duke Energy's operations is presented as Other.
	These Condensed Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and all majority-owned subsidiaries where the respective Duke Energy Registrants have control and those variable interest entities (VIEs) where the respective Duke Energy Registrants are the primary beneficiary. These Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants' proportionate share of certain generation and transmission facilities.
	Duke Energy Carolinas, a wholly owned subsidiary of Duke Energy, is a regulated public utility that generates, transmits, distributes and sells electricity in portions of North Carolina and South Carolina. Duke Energy Carolinas is subject to the regulatory provisions of the North Carolina Utilities Commission (NCUC), the Public Service Commission of South Carolina (PSCSC), the U.S. Nuclear Regulatory Commission (NRC), and the FERC. Substantially all of Duke Energy Carolinas' operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Carolinas' operations include one reportable business segment, Franchised Electric.
	Progress Energy, a wholly owned subsidiary of Duke Energy, is a holding company headquartered in Raleigh, North Carolina, subject to regulation by the FERC. Progress Energy conducts operations through its wholly owned subsidiaries, Duke Energy Progress and Duke Energy Florida. As discussed further in Note 3, Progress Energy's operations include one reportable segment, Franchised Electric.
	Duke Energy Progress, an indirect wholly owned subsidiary of Duke Energy, is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of North Carolina and South Carolina. Duke Energy Progress is subject to the regulatory provisions of the NCUC, the PSCSC, the NRC, and the FERC. Substantially all of Duke Energy Progress' operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Progress' operations include one reportable segment, Franchised Electric.
	Duke Energy Florida, an indirect wholly owned subsidiary of Duke Energy, is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Florida. Duke Energy Florida is subject to the regulatory provisions of the Florida Public Service Commission (FPSC), the NRC, and the FERC. Substantially all of Duke Energy Florida's operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Florida's operations include one reportable segment, Franchised Electric.
	Duke Energy Ohio, an indirect wholly owned subsidiary of Duke Energy, is a combination electric and gas public utility that provides service in portions of Ohio and Kentucky. Operations in Kentucky are conducted through its wholly owned subsidiary, Duke Energy Kentucky, Inc. (Duke Energy Kentucky). Duke Energy Ohio also generates electricity in portions of Ohio, Illinois and Pennsylvania. Duke Energy Ohio's principal lines of business include generation, transmission and distribution of electricity, the sale of and/or transportation of natural gas, and energy marketing. Duke Energy Ohio conducts competitive auctions for retail electricity supply in Ohio whereby the energy price is recovered from retail customers. Duke Energy Kentucky's principal lines of business include generation, transmission and distribution of electricity, as well as the sale of and/or transportation of natural gas. References herein to Duke Energy Ohio include Duke Energy Ohio and its subsidiaries, unless otherwise noted. Duke Energy Ohio is subject to the regulatory provisions of the Public Utilities Commission of Ohio (PUCO), the Kentucky Public Service Commission (KPSC), and the FERC. Duke Energy Ohio applies regulatory accounting treatment to substantially all of the operations in its Franchised Electric and Gas operating segment. See Note 3 for further information about Duke Energy Ohio's business segments.
	Duke Energy Indiana, an indirect wholly owned subsidiary of Duke Energy, is a regulated public utility primarily engaged in the generation, transmission, distribution and sale of electricity in portions of Indiana. Duke Energy Indiana is subject to the regulatory provisions of the Indiana Utility Regulatory Commission (IURC) and the FERC. Substantially all of Duke Energy Indiana's operations are regulated and qualify for regulatory accounting treatment. As discussed further in Note 3, Duke Energy Indiana's operations include one reportable business segment, Franchised Electric.
Use Of Estimates	'
	BASIS OF PRESENTATION
	These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. Because the interim Condensed Consolidated Financial Statements and Notes do not include all information and notes required by GAAP in the U.S. for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the Consolidated Financial Statements and Notes in the Duke Energy Registrants' combined Annual Report on Form 10-K for the year ended December 31, 2012.
	These Condensed Consolidated Financial Statements reflect all normal recurring adjustments in the opinion of the respective companies' management, necessary to fairly present the financial position and results of operations of each of the Duke Energy Registrants. Amounts reported in Duke Energy's interim Condensed Consolidated Statements of Operations and each of the Subsidiary Registrants' interim Condensed Consolidated Statements of Income and Comprehensive Income are not necessarily indicative of amounts expected for the respective annual periods due to effects of seasonal temperature variations on energy consumption, regulatory rulings, timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, and other factors.
	In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.
Unbilled Revenue	'
	UNBILLED REVENUE
	Revenues on sales of electricity and gas are recognized when either the service is provided or the product is delivered. Unbilled revenues are estimated by applying an average rate for retail customers or a contract rate for wholesale customers by the estimated volume of energy delivered but not billed. The amount of unbilled revenues can vary significantly from period to period as a result of numerous factors, including seasonality, weather, customer usage patterns and customer mix.
	Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail and wholesale accounts receivable to Cinergy Receivables Company, LLC (CRC). These transfers meet sales/derecognition criteria and, therefore, Duke Energy Ohio and Duke Energy Indiana account for the transfers of receivables to CRC as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. Receivables for unbilled revenues related to retail and wholesale accounts receivable at Duke Energy Ohio and Duke Energy Indiana included in the sales of accounts receivable to CRC were as shown in the table below.
Income Taxes	'
Income Taxes	Duke Energy and its subsidiaries file income tax returns in the U.S. with federal and various state governmental authorities, and in certain foreign jurisdictions. The taxable income of Duke Energy and its subsidiaries is reflected in Duke Energy's U.S. federal and state income tax returns. These subsidiaries have a tax sharing agreement with Duke Energy where the separate return method is used to allocate tax expenses and benefits to the subsidiaries whose investments or results of operations provide these tax expenses and benefits. The accounting for income taxes essentially represents the income taxes that each of these subsidiaries would incur if it were a separate company filing its own tax return as a C-Corporation.
Excise Taxes	'
Excise Taxes	Certain excise taxes levied by state or local governments are collected by the Duke Energy Registrants from their customers. These taxes, which are required to be paid regardless of the Duke Energy Registrants' ability to collect from the customer, are accounted for on a gross basis. When the Duke Energy Registrants act as an agent, and the tax is not required to be remitted if it is not collected from the customer, the taxes are accounted for on a net basis.
Duke Energy Ohio [Member]	'
Policy Text Block [Line Items]	'
Unbilled Revenue	'
Unbilled Revenue	Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail and wholesale accounts receivable to Cinergy Receivables Company, LLC (CRC). These transfers meet sales/derecognition criteria and, therefore, Duke Energy Ohio and Duke Energy Indiana account for the transfers of receivables to CRC as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. Receivables for unbilled revenues related to retail and wholesale accounts receivable at Duke Energy Ohio and Duke Energy Indiana included in the sales of accounts receivable to CRC were as shown in the table below.
Duke Energy Indiana [Member]	'
Policy Text Block [Line Items]	'
Unbilled Revenue	'
Unbilled Revenue	Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail and wholesale accounts receivable to Cinergy Receivables Company, LLC (CRC). These transfers meet sales/derecognition criteria and, therefore, Duke Energy Ohio and Duke Energy Indiana account for the transfers of receivables to CRC as sales. Accordingly, the receivables sold are not reflected on the Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 11 for further information. Receivables for unbilled revenues related to retail and wholesale accounts receivable at Duke Energy Ohio and Duke Energy Indiana included in the sales of accounts receivable to CRC were as shown in the table below.

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation (Tables)	9 Months Ended
Organization and Basis of Presentation (Tables)	Sep. 30, 2013
Organization And Basis Of Presentation [Line Items]	'
Schedule Of Unbilled Revenues With Restricted Receivables	'

	(in millions)	30-Sep-13		31-Dec-12
	Duke Energy	$	856	$	920
	Duke Energy Carolinas		288		315
	Progress Energy		220		187
	Duke Energy Progress		120		112
	Duke Energy Florida		100		74
	Duke Energy Ohio		33		47
	Duke Energy Indiana		3		3

Duke Energy Ohio [Member]	'
Organization And Basis Of Presentation [Line Items]	'
Schedule of Unbilled Revenues Sold to CRC	'

	(in millions)	30-Sep-13		31-Dec-12
	Duke Energy Ohio	$	65	$	90
	Duke Energy Indiana		126		132

Duke Energy Indiana [Member]	'
Organization And Basis Of Presentation [Line Items]	'
Schedule of Unbilled Revenues Sold to CRC	'

	(in millions)	30-Sep-13		31-Dec-12
	Duke Energy Ohio	$	65	$	90
	Duke Energy Indiana		126		132

Acquisitions_and_Sales_of_Othe1

Acquisitions and Sales of Other Assets (Tables)	9 Months Ended
Acquisitions and Sales of Other Assets (Tables)	Sep. 30, 2013
Significant Acquisitions and Disposals [Line Items]	'
Schedule of Purchase Price Allocation	'

	(in millions)
	Current assets	$	3,204
	Property, plant and equipment		23,141
	Goodwill		12,469
	Other long-term assets, excluding goodwill		9,990
	Total assets		48,804
	Current liabilities, including current maturities of long-term debt		3,593
	Long-term liabilities, preferred stock and noncontrolling interests		10,394
	Long-term debt		16,746
	Total liabilities and preferred stock		30,733
	Total purchase price	$	18,071

Pro Forma Information	'

	(in millions, except per share amounts)	Three Months Ended September 30, 2012		Nine Months Ended September 30, 2012
	Revenues	$	6,727	$	18,309
	Net Income Attributable to Duke Energy Corporation		889		1,888
	Basic and Diluted Earnings Per Share		1.26		2.68

Business_Segments_Tables

Business Segments (Tables)	3 Months Ended																																9 Months Ended
Business Segments (Tables)	Sep. 30, 2013																Sep. 30, 2012																Sep. 30, 2013																				Sep. 30, 2012
Segment Reporting Information [Line Items]	'																'																'																				'
Business Segment Data	'																'																'																				'

			Three Months Ended September 30, 2013																Three Months Ended September 30, 2012																Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)		USFE&G		International Energy		Commercial Power		Total Reportable Segments		Other		Eliminations		Consolidated		(in millions)		USFE&G		International Energy		Commercial Power		Total Reportable Segments		Other		Eliminations		Consolidated		(in millions)		USFE&G			International Energy			Commercial Power			Total Reportable Segments			Other		Eliminations		Consolidated		(in millions)		USFE&G		International Energy		Commercial Power		Total Reportable Segments		Other		Eliminations		Consolidated
	Unaffiliated revenues^(a)(b)(c)		$	5,768	$	370	$	541	$	6,679	$	30	$	―	$	6,709	Unaffiliated revenues		$	5,830	$	382	$	508	$	6,720	$	2	$	―	$	6,722	Unaffiliated revenues^(a)(b)(c)		$	15,731		$	1,168		$	1,527		$	18,426		$	60	$	―	$	18,486	Unaffiliated revenues		$	11,178	$	1,181	$	1,560	$	13,919	$	10	$	―	$	13,929
	Intersegment revenues			18		―		9		27		24		-51		―	Intersegment revenues			12		―		17		29		18		-47		―	Intersegment revenues			35			―			32			67			65		-132		―	Intersegment revenues			29		―		47		76		41		-117		―
		Total revenues	$	5,786	$	370	$	550	$	6,706	$	54	$	-51	$	6,709		Total revenues	$	5,842	$	382	$	525	$	6,749	$	20	$	-47	$	6,722		Total revenues	$	15,766		$	1,168		$	1,559		$	18,493		$	125	$	-132	$	18,486		Total revenues	$	11,207	$	1,181	$	1,607	$	13,995	$	51	$	-117	$	13,929
	Segment income^(a)(b)(c)(d)		$	923	$	116	$	27	$	1,066	$	-76	$	―	$	990	Segment income^(a)(b)		$	790	$	103	$	12	$	905	$	-315	$	―	$	590	Segment income^{(a)(b)(c)(d)(e)(f)}		$	1,932		$	300		$	26		$	2,258		$	-292	$	―	$	1,966	Segment income^(a)(b)		$	1,263	$	350	$	71	$	1,684	$	-356	$	―	$	1,328
	Add back noncontrolling interests component															4	Add back noncontrolling interests component															4	Add back noncontrolling interests component																			7	Add back noncontrolling interests component															12
	Income from discontinued operations, net of tax															14	Income from discontinued operations, net of tax															4	Income from discontinued operations, net of tax																			11	Income from discontinued operations, net of tax															5
	Net income														$	1,008	Net income														$	598	Net income																		$	1,984	Net income														$	1,345
	Segment assets as of September 30, 2013		$	99,269	$	5,669	$	6,852	$	111,790	$	2,658	$	142	$	114,590
																	(a)	USFE&G recorded an impairment related to the Edwardsport Integrated Gasification Combined Cycle (IGCC) project. See Note 4 for additional information on the Edwardsport impairment.															(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.																			(a)	USFE&G recorded an impairment charge related to Duke Energy Indiana's IGCC project. USFE&G also recorded the reversal of expenses of $60 million related to a prior year Voluntary Opportunity Plan in accordance with Duke Energy Carolinas' 2011 rate case. See Note 4 for additional information about the impairment charges.
	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.															(b)	Other includes after-tax costs to achieve the merger with Progress Energy of $293 million. See Note 2 for additional information about the merger.															(b)	In June 2013, Duke Energy Progress implemented revised customer rates approved by the NCUC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.																			(b)	Other includes after-tax costs to achieve the merger with Progress Energy of $306 million. See Note 2 for additional information about the merger.
	(b)	In June 2013, Duke Energy Progress implemented revised customer rates approved by the NCUC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.																															(c)	In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
	(c)	In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.																															(d)	USFE&G recorded an impairment charge related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information about the Crystal River Unit 3 impairment.
	(d)	Other includes after-tax costs to achieve the merger with Progress Energy of $54 million. See Note 2 for additional information about the merger.																															(e)	USFE&G recorded an impairment charge related to Duke Energy Progress' Shearon Harris Nuclear Station (Harris) site. USFE&G also recorded an impairment charge related to Duke Energy Florida's proposed Levy Nuclear Station (Levy). See Note 4 for additional information about the Harris site and Levy site impairments.
																																	(f)	Other includes after-tax costs to achieve the merger with Progress Energy of $139 million. See Note 2 for additional information about the merger.

Duke Energy Carolinas [Member]	'																'																'																				'
Segment Reporting Information [Line Items]	'																'																'																				'
Schedule of Net Loss for Other Segment	'																'																'																				'

																																				Three Months Ended September 30,						Nine Months Ended September 30,
																																	(in millions)			2013			2012			2013			2012
																																	Duke Energy Carolinas			$	-26		$	-119		$	-69		$	-137
																																	Progress Energy				-72			-181			-205			-278
																																	Duke Energy Progress				-20			-109			-40			-119
																																	Duke Energy Florida				-6			-23			-18			-30
																																	Duke Energy Indiana				-5			-14			-13			-19

Progress Energy [Member]	'																'																'																				'
Segment Reporting Information [Line Items]	'																'																'																				'
Schedule of Net Loss for Other Segment	'																'																'																				'

																																				Three Months Ended September 30,						Nine Months Ended September 30,
																																	(in millions)			2013			2012			2013			2012
																																	Duke Energy Carolinas			$	-26		$	-119		$	-69		$	-137
																																	Progress Energy				-72			-181			-205			-278
																																	Duke Energy Progress				-20			-109			-40			-119
																																	Duke Energy Florida				-6			-23			-18			-30
																																	Duke Energy Indiana				-5			-14			-13			-19

Duke Energy Progress [Member]	'																'																'																				'
Segment Reporting Information [Line Items]	'																'																'																				'
Schedule of Net Loss for Other Segment	'																'																'																				'

																																				Three Months Ended September 30,						Nine Months Ended September 30,
																																	(in millions)			2013			2012			2013			2012
																																	Duke Energy Carolinas			$	-26		$	-119		$	-69		$	-137
																																	Progress Energy				-72			-181			-205			-278
																																	Duke Energy Progress				-20			-109			-40			-119
																																	Duke Energy Florida				-6			-23			-18			-30
																																	Duke Energy Indiana				-5			-14			-13			-19

Duke Energy Florida [Member]	'																'																'																				'
Segment Reporting Information [Line Items]	'																'																'																				'
Schedule of Net Loss for Other Segment	'																'																'																				'

																																				Three Months Ended September 30,						Nine Months Ended September 30,
																																	(in millions)			2013			2012			2013			2012
																																	Duke Energy Carolinas			$	-26		$	-119		$	-69		$	-137
																																	Progress Energy				-72			-181			-205			-278
																																	Duke Energy Progress				-20			-109			-40			-119
																																	Duke Energy Florida				-6			-23			-18			-30
																																	Duke Energy Indiana				-5			-14			-13			-19

Duke Energy Ohio [Member]	'																'																'																				'
Segment Reporting Information [Line Items]	'																'																'																				'
Business Segment Data	'																'																'																				'
			Three Months Ended September 30, 2013																Three Months Ended September 30, 2012																Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)		Franchised Electric and Gas		Commercial Power		Total Reportable Segments		Other		Eliminations		Consolidated				(in millions)		Franchised Electric and Gas		Commercial Power		Total Reportable Segments		Other		Eliminations		Consolidated				(in millions)		Franchised Electric and Gas			Commercial Power			Total Reportable Segments			Other			Eliminations		Consolidated				(in millions)		Franchised Electric and Gas		Commercial Power		Total Reportable Segments		Other		Eliminations		Consolidated
	Unaffiliated revenues^(a)		$	421	$	398	$	819	$	―	$	―	$	819			Unaffiliated revenues		$	431	$	326	$	757	$	―	$	―	$	757			Unaffiliated revenues^(a)		$	1,317		$	1,060		$	2,377		$	―		$	―	$	2,377			Unaffiliated revenues		$	1,291	$	1,095	$	2,386	$	―	$	―	$	2,386
	Intersegment revenues			―		6		6		―		-6		―			Intersegment revenues			―		15		15		―		-15		―			Intersegment revenues			―			25			25			―			-25		―			Intersegment revenues			―		42		42		―		-42		―
		Total revenues	$	421	$	404	$	825	$	―	$	-6	$	819				Total revenues	$	431	$	341	$	772	$	―	$	-15	$	757				Total revenues	$	1,317		$	1,085		$	2,402		$	―		$	-25	$	2,377				Total revenues	$	1,291	$	1,137	$	2,428	$	―	$	-42	$	2,386
	Segment income / Consolidated net income^(a)		$	42	$	30	$	72	$	-13	$	―	$	59			Segment income (loss) / Consolidated net income		$	49	$	-17	$	32	$	-18	$	―	$	14			Segment income (loss) / Consolidated net income^(a)		$	122		$	-3		$	119		$	-23		$	―	$	96			Segment income / Consolidated net income		$	113	$	44	$	157	$	-24	$	―	$	133
	Segment assets as of September 30, 2013		$	6,631	$	4,088	$	10,719	$	103	$	-165	$	10,657
																																	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts FE&G. See Note 4 for additional information about the revised customer rates.
	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts FE&G. See Note 4 for additional information about the revised customer rates.

Duke Energy Indiana [Member]	'																'																'																				'
Segment Reporting Information [Line Items]	'																'																'																				'
Schedule of Net Loss for Other Segment	'																'																'																				'

																																				Three Months Ended September 30,						Nine Months Ended September 30,
																																	(in millions)			2013			2012			2013			2012
																																	Duke Energy Carolinas			$	-26		$	-119		$	-69		$	-137
																																	Progress Energy				-72			-181			-205			-278
																																	Duke Energy Progress				-20			-109			-40			-119
																																	Duke Energy Florida				-6			-23			-18			-30
																																	Duke Energy Indiana				-5			-14			-13			-19

Regulatory_Matters_Tables

Regulatory Matters (Tables)	9 Months Ended
Regulatory Matters (Tables)	Sep. 30, 2013
Public Utilities, General Disclosures [Line Items]	'
Schedule of Potential Plant Retirements	'

				30-Sep-13
				Duke Energy			Duke Energy Carolinas		^(b)		Progress Energy			Duke Energy Progress		^(c)(d)	Duke Energy Florida		^(e)	Duke Energy Ohio		^(f)	Duke Energy Indiana		^(g)
	Capacity (in MW)				3,244			200				1,448			575			873			928			668
	Remaining net book value (in millions)^(a)			$	319		$	14			$	171		$	59		$	112		$	10		$	124

	(a)	Included in Property, plant and equipment, net as of September 30, 2013, on the Condensed Consolidated Balance Sheets, unless otherwise noted.
	(b)	Includes Lee Units 1 and 2. Excludes 170 MW Lee Unit 3 that is expected to be converted to gas in 2014. Duke Energy Carolinas expects to retire or convert these units by December 2020 in conjunction with a settlement agreement associated with the Cliffside Unit 6 air permit.
	(c)	Includes Sutton Station, which is expected to be retired by the end of 2013.
	(d)	Remaining net book value of Duke Energy Progress' Sutton Station is included in Generation facilities to be retired, net, on the Condensed Consolidated Balance Sheets at September 30, 2013.
	(e)	Includes Crystal River Units 1 and 2.
	(f)	Includes Beckjord Station Units 2 through 6 and Miami Fort Unit 6. Beckjord units have no remaining book value. Beckjord units 2 and 3 were retired effective October 1, 2013.
	(g)	Includes Wabash River Units 2 through 6. Wabash River Unit 6 is being evaluated for potential conversion to gas. Duke Energy Indiana committed to retire or convert these units by June 2018 in conjunction with a settlement agreement associated with the Edwardsport air permit.

	Duke Energy continues to evaluate the potential need to retire these coal-fired generating facilities earlier than the current estimated useful lives, and plans to seek regulatory recovery for amounts that would not be otherwise recovered when any of these assets are retired. However, such recovery, including recovery of carrying costs on remaining book values, could be subject to future regulatory approvals and therefore cannot be assured.

Duke Energy Florida [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Schedule of FPSC Settlement Agreement Customer Refunds	'
			30-Sep-13
									Remaining Amount to be Refunded
	(in millions)		Total			Refunded to date			2013			2014			2015		2016
	2012 Settlement refund^(a)		$	288		$	97		$	32		$	139		$	10	$	10
	Retirement decision refund			100			―			―			―			40		60
	NEIL proceeds			490			245			81			164			―		―
	Total customer refunds		$	878			342			113			303			50		70
	Accelerated regulatory asset recovery			-135			―			―			-38			-38		-59
	Net customer refunds			743		$	342		$	113		$	265		$	12	$	11

	(a)	See discussion under Customer Rate Matters section below.

Duke Energy Ohio [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Schedule of MISO Exit Fee Obligations	'

	(in millions)		Balance at December 31, 2012			Provision / Adjustments			Cash Reductions			Balance at September 30, 2013^(a)
	Duke Energy Ohio		$	97		$	3		$	-3		$	97

	(a)	As of September 30, 2013, $70 million is recorded as a Regulatory asset on Duke Energy Ohio's Condensed Consolidated Balance Sheets.

Commitments_and_Contingencies_

Commitments and Contingencies (Table)	9 Months Ended
Commitments and Contingencies (Table)	Sep. 30, 2013																	Sep. 30, 2012
Valuation and Qualifying Accounts Disclosure [Line Items]	'																	'
Accrual For Environmental Loss Contingencies	'																	'
	Balance at December 31, 2012		$	75		$	12	$	33	$	14	$	19	$	15	$	8
	Provisions / adjustments			6			―		5		1		4		-1		1	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Cash reductions			-17			―		-6		-2		-4		-8		-2	Balance at December 31, 2011	$	61	$	12	$	23	$	11	$	12	$	28	$	9
	Balance at September 30, 2013		$	64		$	12	$	32	$	13	$	19	$	6	$	7	Provisions / adjustments		43		1		16		4		12		10		2
																		Cash reductions		-19		―		-7		-2		-5		-15		-2
																		Balance at September 30, 2012	$	85	$	13	$	32	$	13	$	19	$	23	$	9

Schedule of Additional Possible Losses in Excess of Recorded Environmental Reserves	'																	'

	(in millions)
	Duke Energy					$	75
	Duke Energy Carolinas						29
	Progress Energy						6
	Duke Energy Progress						3
	Duke Energy Florida						3
	Duke Energy Ohio						35
	Duke Energy Indiana						5

Estimated Costs of Complying With Recently Issued and Proposed EPA Regulations	'																	'

	(in millions)		Range
	Duke Energy		$	650	-	800
	Duke Energy Carolinas			65	-	85
	Progress Energy			7	-	30
	Duke Energy Progress			5	-	10
	Duke Energy Florida			2	-	20
	Duke Energy Ohio			40	-	85
	Duke Energy Indiana			540	-	600

Schedule of Litigation Reserves and Related Insurance Recoveries	'																	'

	(in millions)		30-Sep-13			31-Dec-12
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	782		$	846
	Duke Energy Carolinas^(b)			633			751
	Progress Energy			74			79
	Duke Energy Progress			10			12
	Duke Energy Florida^(c)			43			47
	Duke Energy Indiana			8			8
	Probable Insurance Recoveries^(d)
	Duke Energy^(e)		$	649		$	781
	Duke Energy Carolinas^(e)			649			781

	(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
	(b)	Includes reserves for asbestos-related injuries and damages claims.
	(c)	Includes workers' compensation claims.
	(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Duke Energy Carolinas [Member]	'																	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'																	'
Schedule of Litigation Reserves and Related Insurance Recoveries	'																	'

	(in millions)		30-Sep-13			31-Dec-12
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	782		$	846
	Duke Energy Carolinas^(b)			633			751
	Progress Energy			74			79
	Duke Energy Progress			10			12
	Duke Energy Florida^(c)			43			47
	Duke Energy Indiana			8			8
	Probable Insurance Recoveries^(d)
	Duke Energy^(e)		$	649		$	781
	Duke Energy Carolinas^(e)			649			781

	(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
	(b)	Includes reserves for asbestos-related injuries and damages claims.
	(c)	Includes workers' compensation claims.
	(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Progress Energy [Member]	'																	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'																	'
Schedule of Litigation Reserves and Related Insurance Recoveries	'																	'

	(in millions)		30-Sep-13			31-Dec-12
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	782		$	846
	Duke Energy Carolinas^(b)			633			751
	Progress Energy			74			79
	Duke Energy Progress			10			12
	Duke Energy Florida^(c)			43			47
	Duke Energy Indiana			8			8
	Probable Insurance Recoveries^(d)
	Duke Energy^(e)		$	649		$	781
	Duke Energy Carolinas^(e)			649			781

	(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
	(b)	Includes reserves for asbestos-related injuries and damages claims.
	(c)	Includes workers' compensation claims.
	(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Duke Energy Progress [Member]	'																	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'																	'
Schedule of Litigation Reserves and Related Insurance Recoveries	'																	'

	(in millions)		30-Sep-13			31-Dec-12
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	782		$	846
	Duke Energy Carolinas^(b)			633			751
	Progress Energy			74			79
	Duke Energy Progress			10			12
	Duke Energy Florida^(c)			43			47
	Duke Energy Indiana			8			8
	Probable Insurance Recoveries^(d)
	Duke Energy^(e)		$	649		$	781
	Duke Energy Carolinas^(e)			649			781

	(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
	(b)	Includes reserves for asbestos-related injuries and damages claims.
	(c)	Includes workers' compensation claims.
	(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Duke Energy Florida [Member]	'																	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'																	'
Schedule of Litigation Reserves and Related Insurance Recoveries	'																	'

	(in millions)		30-Sep-13			31-Dec-12
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	782		$	846
	Duke Energy Carolinas^(b)			633			751
	Progress Energy			74			79
	Duke Energy Progress			10			12
	Duke Energy Florida^(c)			43			47
	Duke Energy Indiana			8			8
	Probable Insurance Recoveries^(d)
	Duke Energy^(e)		$	649		$	781
	Duke Energy Carolinas^(e)			649			781

	(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
	(b)	Includes reserves for asbestos-related injuries and damages claims.
	(c)	Includes workers' compensation claims.
	(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Duke Energy Indiana [Member]	'																	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'																	'
Schedule of Litigation Reserves and Related Insurance Recoveries	'																	'

	(in millions)		30-Sep-13			31-Dec-12
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	782		$	846
	Duke Energy Carolinas^(b)			633			751
	Progress Energy			74			79
	Duke Energy Progress			10			12
	Duke Energy Florida^(c)			43			47
	Duke Energy Indiana			8			8
	Probable Insurance Recoveries^(d)
	Duke Energy^(e)		$	649		$	781
	Duke Energy Carolinas^(e)			649			781

	(a)	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
	(b)	Includes reserves for asbestos-related injuries and damages claims.
	(c)	Includes workers' compensation claims.
	(d)	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Debt_and_Credit_Facilities_Tab

Debt and Credit Facilities (Tables)	9 Months Ended
Debt and Credit Facilities (Tables)	Sep. 30, 2013
Debt Instrument [Line Items]	'
Schedule Of Significant Debt Issuances	'

	Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana			Duke Energy
	Unsecured Debt
	January 2013^(a)		Jan-73	5.125	%		$	500		$	―		$	―		$	―		$	500
	June 2013^(b)		Jun-18	2.1	%			500			―			―			―			500
	August 2013^(c)(d)		Aug-23	11	%			―			―			―			―			220
	October 2013^(e)		Oct-23	3.95	%			400			―			―			―			400
	Secured Debt
	February 2013^(f)(g)		Dec-30	2.043	%			―			―			―			―			203
	February 2013^(f)		Jun-37	4.74	%			―			―			―			―			220
	April 2013^(h)		Apr-26	5.456	%			―			―			―			―			230
	First Mortgage Bonds
	March 2013⁽ⁱ⁾		Mar-43	4.1	%			―			500			―			―			500
	June 2013^(j)		Jun-41	4	%			―			48			―			―			48
	July 2013^(k)		Jul-43	4.9	%			―			―			―			350			350
	July 2013^(k)(l)		Jul-16	0.619	%			―			―			―			150			150
	September 2013^(m)		Sep-23	3.8	%			―			―			300			―			300
	September 2013^(m)(n)		Mar-15	0.4	%			―			―			150			―			150
	Total issuances						$	1,400		$	548		$	450		$	500		$	3,771

	(a)	Callable after January 2018 at par. Proceeds from the issuance were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS). The securities were redeemed at par plus accrued and unpaid distributions, payable upon presentation on the redemption date. The remaining net proceeds were used to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 11 for additional information about the QUIPS.
	(b)	Proceeds from the issuance were used to repay $250 million of current maturities. The remaining net proceeds were used for general corporate purposes, including the repayment of outstanding commercial paper.
	(c)	Proceeds from the issuance were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.
	(d)	The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.
	(e)	Proceeds from the issuance were used to repay commercial paper as well as for general corporate purposes.
	(f)	Represents the conversion of construction loans related to a renewable energy project issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.
	(g)	The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.
	(h)	Represents primarily the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.
	(i)	Proceeds from the issuance were used to repay notes payable to affiliated companies as well as for general corporate purposes.
	(j)	Callable after June 2023 at par. Proceeds from the issuance were used to redeem $48 million of First Mortgage Bonds with a higher interest rate.
	(k)	Proceeds from the issuances were used to repay $400 million of current maturities.
	(l)	The debt is floating rate based on 3-month London Interbank Offered Rate (LIBOR) and a fixed spread of 35 basis points.
	(m)	Proceeds from the issuances were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.
	(n)	The debt is floating rate based on 3-month LIBOR plus a fixed spread of 14 basis points.


	Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana			Duke Energy
	Unsecured Debt
	January 2013^(a)		Jan-73	5.125	%		$	500		$	―		$	―		$	―		$	500
	June 2013^(b)		Jun-18	2.1	%			500			―			―			―			500
	August 2013^(c)(d)		Aug-23	11	%			―			―			―			―			220
	October 2013^(e)		Oct-23	3.95	%			400			―			―			―			400
	Secured Debt
	February 2013^(f)(g)		Dec-30	2.043	%			―			―			―			―			203
	February 2013^(f)		Jun-37	4.74	%			―			―			―			―			220
	April 2013^(h)		Apr-26	5.456	%			―			―			―			―			230
	First Mortgage Bonds
	March 2013⁽ⁱ⁾		Mar-43	4.1	%			―			500			―			―			500
	June 2013^(j)		Jun-41	4	%			―			48			―			―			48
	July 2013^(k)		Jul-43	4.9	%			―			―			―			350			350
	July 2013^(k)(l)		Jul-16	0.619	%			―			―			―			150			150
	September 2013^(m)		Sep-23	3.8	%			―			―			300			―			300
	September 2013^(m)(n)		Mar-15	0.4	%			―			―			150			―			150
	Total issuances						$	1,400		$	548		$	450		$	500		$	3,771

	(a)	Callable after January 2018 at par. Proceeds from the issuance were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS). The securities were redeemed at par plus accrued and unpaid distributions, payable upon presentation on the redemption date. The remaining net proceeds were used to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 11 for additional information about the QUIPS.
	(b)	Proceeds from the issuance were used to repay $250 million of current maturities. The remaining net proceeds were used for general corporate purposes, including the repayment of outstanding commercial paper.
	(c)	Proceeds from the issuance were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.
	(d)	The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.
	(e)	Proceeds from the issuance were used to repay commercial paper as well as for general corporate purposes.
	(f)	Represents the conversion of construction loans related to a renewable energy project issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.
	(g)	The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.
	(h)	Represents primarily the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.
(i)	Proceeds from the issuance were used to repay notes payable to affiliated companies as well as for general corporate purposes.
(j)	Callable after June 2023 at par. Proceeds from the issuance were used to redeem $48 million of First Mortgage Bonds with a higher interest rate.
(k)	Proceeds from the issuances were used to repay $400 million of current maturities.
(l)	The debt is floating rate based on 3-month London Interbank Offered Rate (LIBOR) and a fixed spread of 35 basis points.
(m)	Proceeds from the issuances were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.
(n)	The debt is floating rate based on 3-month LIBOR plus a fixed spread of 14 basis points.

Schedule Of Current Maturities	'

	(in millions)		Maturity Date	Interest Rate			30-Sep-13
	Unsecured Debt
	Duke Energy (Parent)		Feb-14	6.3	%		$	750
	Progress Energy (Parent)		Mar-14	6.05	%			300
	Duke Energy (Parent)		Sep-14	3.95	%			500
	First Mortgage Bonds
	Duke Energy Carolinas		Nov-13	5.75	%			400
	Other							357
	Current maturities of long-term debt						$	2,307


	(in millions)		Maturity Date	Interest Rate			30-Sep-13
	Unsecured Debt
	Duke Energy (Parent)		Feb-14	6.3	%		$	750
	Progress Energy (Parent)		Mar-14	6.05	%			300
	Duke Energy (Parent)		Sep-14	3.95	%			500
	First Mortgage Bonds
	Duke Energy Carolinas		Nov-13	5.75	%			400
	Other							357
	Current maturities of long-term debt						$	2,307

Schedule Of Line Of Credit Facilities	'

			30-Sep-13
	(in millions)		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Duke Energy
	Facility size^(a)		$	1,750		$	1,250		$	750		$	750		$	750		$	750		$	6,000
	Reduction to backstop issuances
	Notes payable and commercial paper^(b)			-256			-300			-244			―			-29			-150			-979
	Outstanding letters of credit			-57			-4			-2			-1			―			―			-64
	Tax-exempt bonds			―			-75			―			―			-84			-81			-240
	Available capacity		$	1,437		$	871		$	504		$	749		$	637		$	519		$	4,717

	(a)	Represents the sublimit of each borrower at September 30, 2013.
	(b)	Duke Energy issued $450 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas and Duke Energy Indiana. The balances are classified as long-term borrowings within Long-term Debt in Duke Energy Carolina’s and Duke Energy Indiana’s Condensed Consolidated Balance Sheets.


			30-Sep-13
	(in millions)		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Duke Energy
	Facility size^(a)		$	1,750		$	1,250		$	750		$	750		$	750		$	750		$	6,000
	Reduction to backstop issuances
	Notes payable and commercial paper^(b)			-256			-300			-244			―			-29			-150			-979
	Outstanding letters of credit			-57			-4			-2			-1			―			―			-64
	Tax-exempt bonds			―			-75			―			―			-84			-81			-240
	Available capacity		$	1,437		$	871		$	504		$	749		$	637		$	519		$	4,717

	(a)	Represents the sublimit of each borrower at September 30, 2013.
	(b)	Duke Energy issued $450 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas and Duke Energy Indiana. The balances are classified as long-term borrowings within Long-term Debt in Duke Energy Carolina’s and Duke Energy Indiana’s Condensed Consolidated Balance Sheets.

Goodwill_Tables

Goodwill (Tables)	9 Months Ended									12 Months Ended
Goodwill (Tables)	Sep. 30, 2013									Dec. 31, 2012
Goodwill [Line Items]	'									'
Goodwill By Reportable Operating Segment	'									'
	Acquisitions ^(a)		2		2		-5		-1	(in millions)	USFE&G		Commercial Power		International Energy		Total
	Foreign exchange and other changes		-2		―		-17		-19	Balance at December 31, 2012
	Balance at September 30, 2013									Goodwill	$	15,950	$	933	$	353	$	17,236
	Goodwill		15,950		935		331		17,216	Accumulated impairment charges		―		-871		―		-871
	Accumulated impairment charges		―		-871		―		-871	Balance at December 31, 2012, as adjusted for accumulated impairment charges		15,950		62		353		16,365
	Balance at September 30, 2013, as adjusted for accumulated impairment charges	$	15,950	$	64	$	331	$	16,345

Duke Energy Ohio [Member]	'									'
Goodwill [Line Items]	'									'
Goodwill By Reportable Operating Segment	'									'
	Foreign exchange and other changes		-1		―		-1			(in millions)	Franchised Electric & Gas		Commercial Power		Total
	Balance at September 30, 2013									Balance at December 31, 2012
	Goodwill		1,136		1,188		2,324			Goodwill	$	1,137	$	1,188	$	2,325
	Accumulated impairment charges		-216		-1,188		-1,404			Accumulated impairment charges		-216		-1,188		-1,404
	Balance at September 30, 2013, as adjusted for accumulated impairment charges	$	920	$	―	$	920			Balance at December 31, 2012, as adjusted for accumulated impairment charges		921		―		921

Risk_Management_Derivative_Ins1

Risk Management, Derivative Instruments and Hedging Activities (Tables)	3 Months Ended						9 Months Ended																	12 Months Ended
	Sep. 30, 2013						Sep. 30, 2013																	Dec. 31, 2012
Derivative [Line Items]	'						'																	'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
							Cash flow hedges^(a)(b)			$	1,190		$	―		$	―		$	―		$	―	Cash flow hedges^(a)		$	1,047		$	―		$	―		$	―		$	―
							Undesignated contracts				34			―			―			27			―	Undesignated contracts			290			50			50			27			200
							Total notional amount			$	1,224		$	―		$	―		$	27		$	―	Fair value hedges			250			―			―			250			―
																								Total notional amount		$	1,587		$	50		$	50		$	277		$	200

Underlying Notional Amounts for Commodity Derivative Instruments Accounted for at Fair Value	'						'																	'
									30-Sep-13																31-Dec-12
									Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana				Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
							Electricity-energy (Gigawatt-hours)^(a)			63,264		1,305		925		925		―		59,662		702		Electricity-energy (Gigawatt-hours)^(a)		52,104		2,028		1,850		1,850		―		51,215		97
							Natural gas (millions of decatherms)			536		―		336		129		207		200		―		Natural gas (millions of decatherms)		528		―		348		118		230		180		―

Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Designated as Hedging Instruments
							Commodity contracts
							Current Liabilities: Other		$	―		$	1		$	―		$	2
							Deferred Credits and Other Liabilities: Other			―			―			―			1
							Interest rate contracts
							Current Assets: Other			―			―			2			―
							Investments and Other Assets: Other			21			―			7			―
							Current Liabilities: Other			―			52			―			81
							Deferred Credits and Other Liabilities: Other			―			14			―			35
							Total Derivatives Designated as Hedging Instruments			21			67			9			119
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts
							Current Assets: Other			46			1			41			2
							Investments and Other Assets: Other			167			104			106			50
							Current Liabilities: Other			136			372			106			407
							Deferred Credits and Other Liabilities: Other			4			171			2			255
							Interest rate contracts
							Current Liabilities: Other			―			1			―			76
							Deferred Credits and Other Liabilities: Other			―			4			―			8
							Total Derivatives Not Designated as Hedging Instruments			353			653			255			798
							Total Derivatives		$	374		$	720		$	264		$	917

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Gross amounts recognized		$	159		$	175			$	338		$	265				Gross amounts recognized	$	127		$	96			$	402		$	295
							Gross amounts offset			-142			-108				-168			-122				Gross amounts offset		-114			-54				-151			-90
							Net amount subject to master netting			17			67				170			143				Net amounts subject to master netting		13			42				251			205
							Amounts not subject to master netting			23			17				89			28				Amounts not subject to master netting		22			19				166			54
							Net amounts recognized on the Condensed Consolidated Balance Sheet		$	40	^(a)	$	84	^(b)		$	259	^(c)	$	171	^(d)			Net amounts recognized on the Condensed Consolidated Balance Sheet	$	35	^(a)	$	61	^(b)		$	417	^(c)	$	259	^(d)

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'						'																	'
		Three Months Ended September 30,
	(in millions)	2013			2012				Nine Months Ended September 30,
	Pretax Gains (Losses) Recorded in AOCI						(in millions)		2013				2012
	Interest rate contracts		$	―	$	-4	Pretax Gains (Losses) Recorded in AOCI
	Commodity contracts			―		1	Interest rate contracts			$	71		$	-30
	Total Pretax Gains (Losses) Recorded in AOCI		$	―	$	-3	Commodity contracts				1			1
	Location of Pretax Gains (Losses) Reclassified from AOCI into Earnings^(a)						Total Pretax Gains (Losses) Recorded in AOCI			$	72		$	-29
	Interest rate contracts^(b)						Location of Pretax Gains (Losses) Reclassified from AOCI into Earnings^(a)
	Interest expense		$	―	$	2	Interest rate contracts^(b)
	Total Pretax Losses Reclassified from AOCI into Earnings		$	―	$	2	Interest expense			$	-2		$	―
							Total Pretax Losses Reclassified from AOCI into Earnings			$	-2		$	―

							(a)	Represents the gains and losses on cash flow hedges previously recorded in AOCI during the term of the hedging relationship and reclassified into earnings during the current period.
							(b)	Amounts in AOCI related to terminated hedges are reclassified to earnings as the interest expense is recorded. The effective portion of the hedges will be amortized to interest expense over the term of the related debt.

Undesignated Contracts - Location And Amount Of Pre-Tax Gains And (Losses) Recognized In Income Or As Regulatory Assets Or Liabilities	'						'																	'

		Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)			2013		2012	(in millions)		2013				2012
	Location of Pretax Gains and (Losses) Recognized in Earnings						Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts						Commodity contracts
	Revenue: Regulated electric		$	3	$	-22	Revenue: Regulated electric			$	10		$	-22
	Revenue: Nonregulated electric, natural gas and other			-7		-28	Revenue: Nonregulated electric, natural gas and other				-15			8
	Other income and expenses			―		-1	Other income and expenses				―			-1
	Fuel used in electric generation and purchased power - regulated			-68		-135	Fuel used in electric generation and purchased power - regulated^(a)				-157			-135
	Fuel used in electric generation and purchased power - nonregulated			-2		―	Fuel used in electric generation and purchased power - nonregulated				-20			―
	Interest rate contracts						Interest rate contracts
	Interest expense			-4		-4	Interest expense				-13			-4
	Total Pretax Losses Recognized in Earnings		$	-78	$	-190	Total Pretax (Losses) Gains Recognized in Earnings			$	-195		$	-154
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities						Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts						Commodity contracts^(b)
	Regulatory assets		$	-29	$	61	Regulatory assets			$	-34		$	61
	Regulatory liabilities			6		12	Regulatory liabilities				10			34
	Interest rate contracts						Interest rate contracts^(c)
	Regulatory assets			12		7	Regulatory assets				51			-3
	Total Pretax Losses Recognized as Regulatory Assets or Liabilities		$	-11	$	80	Total Pretax Gains Recognized as Regulatory Assets or Liabilities			$	27		$	92

							(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
							(b)	Amounts are recorded as regulatory assets and liabilities in the Condensed Consolidated Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.
							(c)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
							Aggregate fair value amounts of derivative instruments in a net liability position			$	481		$	211		$	82		$	129		$	268	Aggregate fair value amounts of derivative instruments in a net liability position		$	466		$	286		$	108		$	178		$	176
							Fair value of collateral already posted				138			26			5			21			106	Fair value of collateral already posted			163			59			9			50			104
							Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				200			185			77			108			15	Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered			230			227			99			128			2

Schedule Of Cash Collateral Under Master Netting Arrangements	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Receivables			Payables			Receivables			Payables
							Duke Energy
							Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
							Amounts not offset against net derivative positions			101			―			93			―
							Progress Energy
							Amounts offset against net derivative positions			26			―			58			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Progress
							Amounts offset against net derivative positions			5			―			9			―
							Duke Energy Florida
							Amounts offset against net derivative positions			21			―			49			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Ohio
							Amounts offset against net derivative positions			13			―			15			―
							Amounts not offset against net derivative positions			92			―			92			―
							Duke Energy Indiana
							Amounts not offset against net derivative positions			3			―			―			―

Duke Energy Carolinas [Member]	'						'																	'
Derivative [Line Items]	'						'																	'
Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts^(a)
							Current Liabilities: Other		$	―		$	3		$	―		$	6
							Deferred Credits and Other Liabilities: Other			―			1			―			6
							Total Derivatives Not Designated as Hedging Instruments			―			4			―			12
							Total Derivatives		$	―		$	4		$	―		$	12

							(a)	Substantially all of these contracts receive regulatory accounting treatment.

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Amounts not subject to master netting			―			―				3			1				Amounts not subject to master netting		―			―				6			6
							Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―		$	―			$	3	^(a)	$	1	^(b)			Net amounts recognized on the Condensed Consolidated Balance Sheet	$	―		$	―			$	6	^(a)	$	6	^(b)

Progress Energy [Member]	'						'																	'
Derivative [Line Items]	'						'																	'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk	'						'																	'
																										31-Dec-12
																								(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
																								Cash flow hedges^(a)		$	1,047		$	―		$	―		$	―		$	―
																								Undesignated contracts			290			50			50			27			200
																								Fair value hedges			250			―			―			250			―
																								Total notional amount		$	1,587		$	50		$	50		$	277		$	200

Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Designated as Hedging Instruments
							Commodity contracts
							Current Liabilities: Other		$	―		$	―		$	―		$	2
							Deferred Credits and Other Liabilities: Other			―			1			―			1
							Total Derivatives Designated as Hedging Instruments			―			1			―			3
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts^(a)
							Current Assets: Other			―			―			3			―
							Investments and Other Assets: Other			―			―			8			―
							Current Liabilities: Other			1			159			―			231
							Deferred Credits and Other Liabilities: Other			2			125			―			195
							Interest rate contracts
							Current Liabilities: Other			―			―			―			11
							Total Derivatives Not Designated as Hedging Instruments			3			284			11			437
							Total Derivatives		$	3		$	285		$	11		$	440

							(a)	Substantially all of these contracts receive regulatory treatment.

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Gross amounts recognized		$	1		$	2			$	159		$	122				Gross amounts recognized	$	3		$	8			$	244		$	192
							Gross amounts offset			-1			-1				-13			-15				Gross amounts offset		―			―				-22			-36
							Net amount subject to master netting			―			1				146			107				Net amount subject to master netting		3			8				222			156
							Amounts not subject to master netting			―			―				―			4				Amounts not subject to master netting		―			―				―			4
							Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―	^(a)	$	1	^(b)		$	146	^(c)	$	111	^(d)			Net amounts recognized on the Condensed Consolidated Balance Sheet	$	3	^(a)	$	8	^(b)		$	222	^(c)	$	160	^(d)

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'						'																	'
		Three Months Ended September 30,
	(in millions)	2013			2012				Nine Months Ended September 30,
	Pretax Losses Recorded in AOCI						(in millions)		2013				2012
	Commodity contracts			―		1	Pretax Gains (Losses) Recorded in AOCI
	Total Pretax Losses Recorded in AOCI		$	―	$	1	Interest rate contracts			$	―		$	-11
	Location of Pretax Losses Reclassified from AOCI into Earnings^(a)						Commodity contracts				1			1
	Interest rate contracts^(b)						Total Pretax Gains (Losses) Recorded in AOCI			$	1		$	-10
	Interest expense		$	-5	$	-2	Location of Pretax Losses Reclassified from AOCI into Earnings^(a)
	Total Pretax Losses Reclassified from AOCI into Earnings		$	-5	$	-2	Interest rate contracts^(b)
							Interest expense			$	-5		$	-12
							Total Pretax Losses Reclassified from AOCI into Earnings			$	-5		$	-12

							(a)	Represents the gains and losses on cash flow hedges previously recorded in AOCI during the term of the hedging relationships and reclassified into earnings during the current period.
							(b)	Amounts in AOCI related to terminated hedges are reclassified to earnings as the interest expense is recorded. The effective portion of the hedges will be amortized to interest expense over the term of the related debt.

Undesignated Contracts - Location And Amount Of Pre-Tax Gains And (Losses) Recognized In Income Or As Regulatory Assets Or Liabilities	'						'																	'

		Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)			2013		2012	(in millions)		2013				2012
	Location of Pretax Gains and (Losses) Recognized in Earnings						Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts						Commodity contracts
	Operating revenues		$	3	$	-9	Operating revenues			$	10		$	-9
	Fuel used in electric generation and purchased power^(a)			-68		-135	Fuel used in electric generation and purchased power^(a)				-157			-395
	Interest rate contracts						Interest rate contracts
	Interest expense			-4		-4	Interest expense				-13			-4
	Total Pretax Losses Recognized in Earnings		$	-69	$	-148	Total Pretax Losses Recognized in Earnings			$	-160		$	-408
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities						Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(b)						Commodity contracts^(b)
	Regulatory assets		$	-31	$	60	Regulatory assets			$	-34		$	-108
	Interest rate contracts^(c)						Interest rate contracts^(c)
	Regulatory assets			4		2	Regulatory assets				13			2
	Total Pretax (Losses) Gains Recognized as Regulatory Assets or Liabilities		$	-27	$	62	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities			$	-21		$	-106

							(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
							(b)	Amounts are recorded as regulatory assets and liabilities in the Condensed Consolidated Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.
							(c)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
							Aggregate fair value amounts of derivative instruments in a net liability position			$	481		$	211		$	82		$	129		$	268	Aggregate fair value amounts of derivative instruments in a net liability position		$	466		$	286		$	108		$	178		$	176
							Fair value of collateral already posted				138			26			5			21			106	Fair value of collateral already posted			163			59			9			50			104
							Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				200			185			77			108			15	Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered			230			227			99			128			2

Schedule Of Cash Collateral Under Master Netting Arrangements	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Receivables			Payables			Receivables			Payables
							Duke Energy
							Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
							Amounts not offset against net derivative positions			101			―			93			―
							Progress Energy
							Amounts offset against net derivative positions			26			―			58			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Progress
							Amounts offset against net derivative positions			5			―			9			―
							Duke Energy Florida
							Amounts offset against net derivative positions			21			―			49			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Ohio
							Amounts offset against net derivative positions			13			―			15			―
							Amounts not offset against net derivative positions			92			―			92			―
							Duke Energy Indiana
							Amounts not offset against net derivative positions			3			―			―			―

Duke Energy Progress [Member]	'						'																	'
Derivative [Line Items]	'						'																	'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk	'						'																	'
																										31-Dec-12
																								(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
																								Cash flow hedges^(a)		$	1,047		$	―		$	―		$	―		$	―
																								Undesignated contracts			290			50			50			27			200
																								Fair value hedges			250			―			―			250			―
																								Total notional amount		$	1,587		$	50		$	50		$	277		$	200

Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Designated as Hedging Instruments
							Commodity contracts
							Current Liabilities: Other		$	―		$	―		$	―		$	1
							Deferred Credits and Other Liabilities: Other			―			―			―			1
							Total Derivatives Designated as Hedging Instruments			―			―			―			2
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts^(a)
							Current Assets: Other			―			―			1			―
							Investments and Other Assets: Other			―			―			1			―
							Current Liabilities: Other			―			65			―			85
							Deferred Credits and Other Liabilities: Other			1			43			―			68
							Interest rate contracts
							Current Liabilities: Other			―			―			―			11
							Total Derivatives Not Designated as Hedging Instruments			1			108			2			164
							Total Derivatives		$	1		$	108		$	2		$	166

							(a)	Substantially all of these contracts receive regulatory treatment.

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Gross amounts recognized		$	―		$	1			$	65		$	43				Gross amounts recognized	$	1		$	1			$	97		$	69
							Gross amounts offset			―			―				-3			-2				Gross amounts offset		―			―				-2			-7
							Net amount subject to master netting			―			1				62			41				Net amount subject to master netting		1			1				95			62
							Amounts not subject to master netting			―			―				―			―				Amounts not subject to master netting		―			―				―			―
							Net amounts recognized on the Condensed Consolidated Balance Sheet		$	―	^(a)	$	1	^(b)		$	62	^(c)	$	41	^(d)			Net amounts recognized on the Condensed Consolidated Balance Sheet	$	1	^(a)	$	1	^(b)		$	95	^(c)	$	62	^(d)

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'						'																	'
							The amounts of gains and losses recognized on derivative instruments designated and qualifying as cash flow hedges by type of derivative contract, and the Condensed Consolidated Statements of Operations and Comprehensive Income line items in which such gains and losses were included when reclassified from AOCI were as follows.

									Nine Months Ended September 30,
							(in millions)		2013				2012
							Pretax Gains and (Losses) Recorded in AOCI
							Interest rate contracts^(b)			$	―		$	-7
							Total Pretax Losses Recorded in AOCI			$	―		$	-7
							Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings^(a)
							Interest rate contracts
							Interest expense			$	―		$	-5
							Total Pretax Losses Reclassified from AOCI into Earnings			$	―		$	-5

							(a)	Represents the gains and losses on cash flow hedges previously recorded in AOCI during the term of the hedging relationships and reclassified into earnings during the current period.
							(b)	Amounts in AOCI related to terminated hedges are reclassified to earnings as the interest expense is recorded. The effective portion of the hedges will be amortized to interest expense over the term of the related debt.

Undesignated Contracts - Location And Amount Of Pre-Tax Gains And (Losses) Recognized In Income Or As Regulatory Assets Or Liabilities	'						'																	'

		Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)	2013			2012		(in millions)		2013				2012
	Location of Pretax Gains and (Losses) Recognized in Earnings						Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts						Commodity contracts
	Operating revenues		$	3	$	-9	Operating revenues			$	10		$	-9
	Fuel used in electric generation and purchased power ^(a)			-24		-35	Fuel used in electric generation and purchased power^(a)				-53			-100
	Interest rate contracts						Interest rate contracts
	Interest expense			-3		-3	Interest expense				-9			-3
	Total Pretax Losses Recognized in Earnings		$	-24	$	-47	Total Pretax Losses Recognized in Earnings			$	-52		$	-112
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities						Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(b)						Commodity contracts^(b)
	Regulatory assets		$	-11	$	15	Regulatory assets			$	-18		$	-34
	Interest rate contracts^(c)						Interest rate contracts^(c)
	Regulatory asses			3		2	Regulatory assets				10			2
	Total Pretax (Losses) Gains Recognized as Regulatory Assets or Liabilities		$	-8	$	17	Total Pretax Losses Recognized as Regulatory Assets or Liabilities			$	-8		$	-32

							(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
							(b)	Amounts are recorded in regulatory assets and liabilities in the Condensed Consolidated Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.
							(c)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
							Aggregate fair value amounts of derivative instruments in a net liability position			$	481		$	211		$	82		$	129		$	268	Aggregate fair value amounts of derivative instruments in a net liability position		$	466		$	286		$	108		$	178		$	176
							Fair value of collateral already posted				138			26			5			21			106	Fair value of collateral already posted			163			59			9			50			104
							Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				200			185			77			108			15	Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered			230			227			99			128			2

Schedule Of Cash Collateral Under Master Netting Arrangements	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Receivables			Payables			Receivables			Payables
							Duke Energy
							Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
							Amounts not offset against net derivative positions			101			―			93			―
							Progress Energy
							Amounts offset against net derivative positions			26			―			58			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Progress
							Amounts offset against net derivative positions			5			―			9			―
							Duke Energy Florida
							Amounts offset against net derivative positions			21			―			49			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Ohio
							Amounts offset against net derivative positions			13			―			15			―
							Amounts not offset against net derivative positions			92			―			92			―
							Duke Energy Indiana
							Amounts not offset against net derivative positions			3			―			―			―

Duke Energy Florida [Member]	'						'																	'
Derivative [Line Items]	'						'																	'
Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Designated as Hedging Instruments
							Commodity contracts
							Current Liabilities: Other		$	―		$	―		$	―		$	1
							Total Derivatives Designated as Hedging Instruments			―			―			―			1
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts^(a)
							Current Assets: Other			―			―			2			―
							Investments and Other Assets: Other			―			―			7			―
							Current Liabilities: Other			1			94			―			146
							Deferred Credits and Other Liabilities: Other			1			79			―			123
							Total Derivatives Not Designated as Hedging Instruments			2			173			9			269
							Total Derivatives		$	2		$	173		$	9		$	270

							(a)	Substantially all of these contracts receive regulatory treatment.

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Gross amounts recognized		$	1		$	1			$	94		$	79				Gross amounts recognized	$	2		$	7			$	147		$	123
							Gross amounts offset			-1			-1				-10			-13				Gross amounts offset		―			―				-20			-29
							Net amount subject to master netting			―			―				84			66				Net amount subject to master netting		2			7				127			94
							Amounts not subject to master netting			―			―				―			―				Amounts not subject to master netting		―			―				―			―
							Net amounts recognized on the Condensed Balance Sheet		$	―	^(a)	$	―	^(b)		$	84	^(c)	$	66	^(d)			Net amounts recognized on the Condensed Balance Sheet	$	2	^(a)	$	7	^(b)		$	127	^(c)	$	94	^(d)

Undesignated Contracts - Location And Amount Of Pre-Tax Gains And (Losses) Recognized In Income Or As Regulatory Assets Or Liabilities	'						'																	'

		Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)	2013			2012		(in millions)		2013				2012
	Location of Pretax Gains and (Losses) Recognized in Earnings						Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts						Commodity contracts
	Fuel used in electric generation and purchased power^(a)		$	-45	$	-100	Fuel used in electric generation and purchased power^(a)			$	-105		$	-295
	Interest rate contracts						Interest rate contracts
	Interest expense			-1		-1	Interest expense				-3			-1
	Total Pretax Losses Recognized in Earnings		$	-46	$	-101	Total Pretax Losses Recognized in Earnings			$	-108		$	-296
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities						Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(b)						Commodity contracts^(b)
	Regulatory assets		$	-19	$	45	Regulatory assets			$	-16		$	-74
	Interest rate contracts						Interest rate contracts
	Regulatory assets			1		―	Regulatory assets				3			―
	Total Pretax (Losses) Gains Recognized as Regulatory Assets or Liabilities		$	-18	$	45	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities			$	-13		$	-74

							(a)	After the derivatives are settled and the fuel is consumed, gains or losses are passed through the fuel cost-recovery clause.
							(b)	Amounts are recorded in regulatory assets and liabilities in the Condensed Balance Sheets until gains or losses are passed through the fuel cost-recovery clause.

Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
							Aggregate fair value amounts of derivative instruments in a net liability position			$	481		$	211		$	82		$	129		$	268	Aggregate fair value amounts of derivative instruments in a net liability position		$	466		$	286		$	108		$	178		$	176
							Fair value of collateral already posted				138			26			5			21			106	Fair value of collateral already posted			163			59			9			50			104
							Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				200			185			77			108			15	Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered			230			227			99			128			2

Schedule Of Cash Collateral Under Master Netting Arrangements	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Receivables			Payables			Receivables			Payables
							Duke Energy
							Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
							Amounts not offset against net derivative positions			101			―			93			―
							Progress Energy
							Amounts offset against net derivative positions			26			―			58			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Progress
							Amounts offset against net derivative positions			5			―			9			―
							Duke Energy Florida
							Amounts offset against net derivative positions			21			―			49			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Ohio
							Amounts offset against net derivative positions			13			―			15			―
							Amounts not offset against net derivative positions			92			―			92			―
							Duke Energy Indiana
							Amounts not offset against net derivative positions			3			―			―			―

Duke Energy Ohio [Member]	'						'																	'
Derivative [Line Items]	'						'																	'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
							Cash flow hedges^(a)(b)			$	1,190		$	―		$	―		$	―		$	―	Cash flow hedges^(a)		$	1,047		$	―		$	―		$	―		$	―
							Undesignated contracts				34			―			―			27			―	Undesignated contracts			290			50			50			27			200
							Total notional amount			$	1,224		$	―		$	―		$	27		$	―	Fair value hedges			250			―			―			250			―
																								Total notional amount		$	1,587		$	50		$	50		$	277		$	200

Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Designated as Hedging Instruments
							Interest rate contracts
							Current Assets: Other		$			$	―		$	2		$	―
							Total Derivatives Designated as Hedging Instruments			―			―			2			―
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts
							Current Assets: Other			21			6			31			4
							Investments and Other Assets: Other			158			103			81			51
							Current Liabilities: Other			134			160			106			132
							Deferred Credits and Other Liabilities: Other			1			17			―			4
							Interest rate contracts
							Current Liabilities: Other			―			―			―			1
							Deferred Credits and Other Liabilities: Other			―			4			―			7
							Total Derivatives Not Designated as Hedging Instruments			314			290			218			199
							Total Derivatives		$	314		$	290		$	220		$	199

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Gross amounts recognized		$	155		$	159			$	165		$	120				Gross amounts recognized	$	137		$	81			$	136		$	55
							Gross amounts offset			-141			-105				-154			-105				Gross amounts offset		-110			-51				-125			-51
							Net amount subject to master netting			14			54				11			15				Net amount subject to master netting		27			30				11			4
							Amounts not subject to master netting			―			―				1			4				Amounts not subject to master netting		2			―				1			7
							Net amounts recognized on the Condensed Consolidated Balance Sheet		$	14	^(a)	$	54	^(b)		$	12	^(c)	$	19	^(d)			Net amounts recognized on the Condensed Consolidated Balance Sheet	$	29	^(a)	$	30	^(b)		$	12	^(c)	$	11	^(d)

Undesignated Contracts - Location And Amount Of Pre-Tax Gains And (Losses) Recognized In Income Or As Regulatory Assets Or Liabilities	'						'																	'

		Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)	2013			2012		(in millions)		2013				2012
	Location of Pretax Gains and (Losses) Recognized in Earnings						Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts						Commodity contracts
	Revenue: Nonregulated electric, natural gas and other		$	5	$	-42	Revenue: Nonregulated electric, natural gas and other			$	-8		$	33
	Fuel used in electric generation and purchased power - nonregulated			-2		―	Fuel used in electric generation and purchased power - nonregulated				-20			―
	Total Pretax (Losses) Gains Recognized in Earnings		$	3	$	-42	Interest rate contracts
							Interest expense				-1			-1
							Total Pretax (Losses) Gains Recognized in Earnings			$	-29		$	32
							Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
							Commodity contracts
							Regulatory assets			$	―		$	-2
							Regulatory liabilities							1
							Interest rate contracts
							Regulatory assets				3			―
							Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities			$	3		$	-1

Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'						'																	'
										30-Sep-13																31-Dec-12
							(in millions)			Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio		(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio
							Aggregate fair value amounts of derivative instruments in a net liability position			$	481		$	211		$	82		$	129		$	268	Aggregate fair value amounts of derivative instruments in a net liability position		$	466		$	286		$	108		$	178		$	176
							Fair value of collateral already posted				138			26			5			21			106	Fair value of collateral already posted			163			59			9			50			104
							Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered				200			185			77			108			15	Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered			230			227			99			128			2

Schedule Of Cash Collateral Under Master Netting Arrangements	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Receivables			Payables			Receivables			Payables
							Duke Energy
							Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
							Amounts not offset against net derivative positions			101			―			93			―
							Progress Energy
							Amounts offset against net derivative positions			26			―			58			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Progress
							Amounts offset against net derivative positions			5			―			9			―
							Duke Energy Florida
							Amounts offset against net derivative positions			21			―			49			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Ohio
							Amounts offset against net derivative positions			13			―			15			―
							Amounts not offset against net derivative positions			92			―			92			―
							Duke Energy Indiana
							Amounts not offset against net derivative positions			3			―			―			―

Duke Energy Indiana [Member]	'						'																	'
Derivative [Line Items]	'						'																	'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk	'						'																	'
																										31-Dec-12
																								(in millions)		Duke Energy			Progress Energy			Duke Energy Progress			Duke Energy Ohio			Duke Energy Indiana
																								Cash flow hedges^(a)		$	1,047		$	―		$	―		$	―		$	―
																								Undesignated contracts			290			50			50			27			200
																								Fair value hedges			250			―			―			250			―
																								Total notional amount		$	1,587		$	50		$	50		$	277		$	200

Location And Fair Value Amounts Of Derivatives Reflected In The Condensed Consolidated Balance Sheets	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Asset			Liability			Asset			Liability
							Derivatives Not Designated as Hedging Instruments
							Commodity contracts^(a)
							Current Assets: Other		$	14		$	―		$	10		$	―
							Interest rate contracts
							Current Liabilities: Other			―			―			―			63
							Total Derivatives Not Designated as Hedging Instruments			14			―			10			63
							Total Derivatives		$	14		$	―		$	10		$	63

							(a)	Substantially all of these contracts receive regulatory treatment.

Offsetting Assets and Liabilities	'						'																	'
									30-Sep-13																31-Dec-12
									Derivative Assets							Derivative Liabilities									Derivative Assets							Derivative Liabilities
							(in millions)		Current			Non-Current				Current			Non-Current					(in millions)	Current			Non-Current				Current			Non-Current
							Gross amounts recognized		$	14		$	―			$	―		$	―				Amounts not subject to master netting		10			―				63			―
							Net amount subject to master netting			14			―				―			―				Net amounts recognized on the Condensed Consolidated Balance Sheet	$	10	^(a)	$	―			$	63	^(b)	$	―
							Net amounts recognized on the Condensed Consolidated Balance Sheet		$	14	^(a)	$	―			$	―	^(b)	$	―

Undesignated Contracts - Location And Amount Of Pre-Tax Gains And (Losses) Recognized In Income Or As Regulatory Assets Or Liabilities	'						'																	'

		Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)	2013			2012		(in millions)		2013				2012
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities						Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts						Commodity contracts
	Regulatory assets		$	2	$	11	Operating Revenues			$	1		$	―
	Regulatory liabilities			6		―	Fuel used in electric generation and purchased power				―			2
	Interest rate contracts^(a)						Total Pretax (Losses) Gains Recognized in Earnings			$	1		$	2
	Regulatory assets			6		4	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Total Pretax Gains Recognized as Regulatory Assets or Liabilities		$	14	$	15	Commodity contracts
							Regulatory liabilities				10			33
							Interest rate contracts^(a)
							Regulatory assets				34			-5
							Total Pretax Gains Recognized as Regulatory Assets or Liabilities			$	44		$	28

							(a)	Amounts in regulatory assets and liabilities related to terminated hedges are reclassified to earnings as the interest expense is recorded. The hedges will be amortized to interest expense over the term of the related debt.

Schedule Of Cash Collateral Under Master Netting Arrangements	'						'																	'

									30-Sep-13						31-Dec-12
							(in millions)		Receivables			Payables			Receivables			Payables
							Duke Energy
							Amounts offset against net derivative positions		$	40		$	―		$	73		$	―
							Amounts not offset against net derivative positions			101			―			93			―
							Progress Energy
							Amounts offset against net derivative positions			26			―			58			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Progress
							Amounts offset against net derivative positions			5			―			9			―
							Duke Energy Florida
							Amounts offset against net derivative positions			21			―			49			―
							Amounts not offset against net derivative positions			―			―			1			―
							Duke Energy Ohio
							Amounts offset against net derivative positions			13			―			15			―
							Amounts not offset against net derivative positions			92			―			92			―
							Duke Energy Indiana
							Amounts not offset against net derivative positions			3			―			―			―

Fair_Value_of_Financial_Assets1

Fair Value of Financial Assets and Liabilities (Tables)	3 Months Ended																						9 Months Ended																								12 Months Ended
Fair Value of Financial Assets and Liabilities (Tables)	Sep. 30, 2013												Sep. 30, 2012										Sep. 30, 2013														Sep. 30, 2012										Dec. 31, 2012
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																										30-Sep-13																								31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Investments in available-for-sale auction rate securities^(a)			$	25		$	―		$	―		$	25											Investments in available-for-sale auction rate securities^(a)			$	29		$	―		$	―		$	29
																							Nuclear decommissioning trust fund equity securities				3,280			3,199			59			22											Nuclear decommissioning trust fund equity securities				2,837			2,762			54			21
																							Nuclear decommissioning trust fund debt securities				1,525			392			1,083			50											Nuclear decommissioning trust fund debt securities				1,405			317			1,040			48
																							Other trading and available-for-sale equity securities^(b)				93			83			10			―											Other trading and available-for-sale equity securities^(b)				72			63			9			―
																							Other trading and available-for-sale debt securities^(c)				414			57			357			―											Other trading and available-for-sale debt securities^(c)				602			40			562			―
																							Derivative assets^(b)				127			32			22			73											Derivative assets^(b)				103			18			22			63
																								Total assets			5,464			3,763			1,531			170												Total assets			5,048			3,200			1,687			161
																							Derivative liabilities^(d)				-473			-15			-347			-111											Derivative liabilities^(d)				-756			-17			-591			-148
																								Net assets		$	4,991		$	3,748		$	1,184		$	59												Net assets		$	4,292		$	3,183		$	1,096		$	13

																																															(a)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
																																															(b)	Included in Other within Current Assets and Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
																																															(c)	Included in Other within Investments and Other Assets and Short-term Investments on the Condensed Consolidated Balance Sheets.
																																															(d)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'												'										'														'										'
			Three Months Ended September 30, 2013																							Nine Months Ended September 30, 2013													Nine Months Ended September 30, 2012
	(in millions)		Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)		Total				Three Months Ended September 30, 2012								(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total		(in millions)		Available-for-Sale Auction Rate Securities		Available-for-Sale NDTF Investments		Derivatives (net)		Total
	Balance at June 30, 2013		$	26		$	71		$	-87	$	10	(in millions)		Available-for-Sale Auction Rate Securities		Available-for-Sale NDTF Investments		Derivatives (net)		Total		Balance at December 31, 2012			$	29		$	69		$	-85		$	13	Balance at December 31, 2011		$	71	$	53	$	-39	$	85
	Total pretax realized or unrealized gains (losses) included in earnings:												Balance at June 30, 2012		$	41	$	64	$	-19	$	86	Total pretax realized or unrealized gains (losses) included in earnings:														Amounts acquired in Progress Energy Merger			―		―		-30		-30
		Revenue: Regulated electric		―			―			4		4	Amounts acquired in Progress Merger			―		―		-30		-30		Revenue: Regulated electric			―			―			5			5	Total pretax realized or unrealized losses included in earnings:
		Revenue: Nonregulated electric, natural gas, and other		―			―			9		9	Total pretax realized or unrealized gains (losses) included in earnings:											Revenue: Nonregulated electric, natural gas, and other			―			―			-13			-13		Revenue: Regulated electric		―		―		37		37
	Total pretax gains included in other comprehensive income:													Revenue: Regulated electric		―		―		12		12	Total pretax gains included in other comprehensive income:															Revenue: Nonregulated electric, natural gas, and other		―		―		-9		-9
		Gains on available for sale securities and other		1			―			―		1		Revenue: Nonregulated electric, natural gas, and other		―		―		-6		-6		Losses on available for sale securities and other			-1			―			―			-1	Total pretax gains included in other comprehensive income:
	Purchases, sales, issuances and settlements:												Total pretax gains included in other comprehensive income:										Purchases, sales, issuances and settlements:															Gains on available for sale securities and other		9		―		―		9
		Purchases		―			2			―		2	Purchases, sales, issuances and settlements:											Purchases			―			5			21			26	Purchases, sales, issuances and settlements:
		Sales		―			-2			―		-2		Purchases		―		1		―		1		Sales			―			-5			―			-5		Purchases		―		10		22		32
		Issuances		―			―			4		4		Issuances		―		―		-24		-24		Issuances			―			―			9			9		Issuances		―		―		-24		-24
		Settlements		-2			―			-3		-5		Settlements				―		-10		-10		Settlements			-3			―			-5			-8		Settlements		-39		―		-34		-73
	Transfers in and out of Level 3 due to observability of inputs			―			―			34		34	Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities			―		1		2		3	Transfers in and out of Level 3 due to observability of inputs				―			―			34			34	Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities			―		3		2		5
	Total gains (losses) included on the Consolidated Balance Sheet as regulatory assets or liabilities			―			1			1		2	Balance at September 30, 2012		$	41	$	66	$	-75	$	32	Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				―			3			-4			-1	Balance at September 30, 2012		$	41	$	66	$	-75	$	32
	Balance at September 30, 2013		$	25		$	72		$	-38	$	59											Balance at September 30, 2013			$	25		$	72		$	-38		$	59	Pretax amounts included in the Condensed Consolidated Statement of Operations related to Level 3 measurements outstanding at September 30, 2012.
	Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013																						Pretax amounts included in the Condensed Consolidated Statement of Operations related to Level 3 measurements outstanding at September 30, 2013															Revenue: Nonregulated electric, natural gas, and other	$	―	$	―	$	5	$	5
		Revenue: Regulated electric	$	―		$	―		$	3	$	3												Revenue: Regulated electric		$	―		$	―		$	5		$	5	Total		$	―	$	―	$	5	$	5
		Revenue: Nonregulated electric, natural gas, and other		―			―			-2		-2												Revenue: Nonregulated electric, natural gas, and other			―			―			-26			-26
	Total		$	―		$	―		$	1	$	1											Total			$	―		$	―		$	-21		$	-21

Schedule of Long-term debt, including current	'												'										'														'										'
																									30-Sep-13						31-Dec-12
																							(in millions)		Book Value			Fair Value			Book Value			Fair Value
																							Duke Energy ^(a)		$	39,709		$	42,142		$	39,461		$	44,001
																							Duke Energy Carolinas^(b)			8,739			9,445			8,741			10,096
																							Progress Energy			13,815			14,989			14,428			16,563
																							Duke Energy Progress			4,936			5,053			4,840			5,277
																							Duke Energy Florida			4,887			5,424			5,320			6,222
																							Duke Energy Ohio			2,188			2,263			1,997			2,117
																							Duke Energy Indiana			3,798			4,143			3,702			4,268

																							(a)	Includes book value of Non-recourse long-term debt of variable interest entities of $1,265 million and $852 million September 30, 2013 and December 31, 2012, respectively.
																							(b)	Includes book value of Non-recourse long-term debt of variable interest entities of $300 million at both September 30, 2013 and December 31, 2012, respectively.

Quantitative Information Table - Level 3	'												'										'														'										'
																									30-Sep-13
																							Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range																		31-Dec-12
																							Duke Energy																								Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
																							Commodity natural gas contracts		$	-43		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.47	-	10.36													Duke Energy
																							FERC mitigation power sale agreements			-4		Discounted cash flow		Forward electricity curves - price per megawatt-hour (MWh)		25.79	-	48.34													Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
																							Financial transmission rights (FTRs)			15		RTO market pricing		FTR price - per MWh		-1.53	-	10.86													FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Commodity power contracts			5		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
																							Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	122.64													Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
																							Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		29.3	-	100.8													Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
																							Reserves			-12				Bid-ask spreads, implied volatility, probability of default																	Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
																							Total Level 3 derivatives		$	-38																					Reserves			-12				Bid-ask spreads, implied volatility, probability of default
																							Duke Energy Carolinas																								Total Level 3 derivatives		$	-85
																							FERC mitigation power sale agreements		$	-4		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	-	48.34													Duke Energy Carolinas
																							Duke Energy Ohio																								FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
																							Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	-0.09	-	0.46													Progress Energy
																							Commodity power contracts			13		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Commodity natural gas contracts			-9		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.47	-	4.55													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Reserves			-11				Bid-ask spreads, implied volatility, probability of default																	Total Level 3 derivatives		$	-38
																							Total Level 3 derivatives		$	-6																					Duke Energy Progress
																							Duke Energy Indiana																								Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Financial transmission rights (FTRs)		$	14		RTO market pricing		FTR price - per MWh	$	-1.53	-	10.86													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Ohio
																																															Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
																																															Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
																																															Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
																																															Reserves			-11				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-6
																																															Duke Energy Indiana
																																															Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

Duke Energy Carolinas [Member]	'												'										'														'										'
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																											30-Sep-13																							31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Investments in available-for-sale auction rate securities^(a)			$	3		$	―		$	―		$	3											Investments in available-for-sale auction rate securities^(a)			$	3		$	―		$	―		$	3
																							Nuclear decommissioning trust fund equity securities				1,790			1,715			53			22											Nuclear decommissioning trust fund equity securities				1,592			1,523			48			21
																							Nuclear decommissioning trust fund debt securities				883			220			613			50											Nuclear decommissioning trust fund debt securities				762			155			559			48
																								Total assets			2,676			1,935			666			75												Total assets			2,357			1,678			607			72
																							Derivative liabilities^(b)				-4			―			―			-4											Derivative liabilities^(b)				-12			―			―			-12
																								Net assets		$	2,672		$	1,935		$	666		$	71												Net Assets		$	2,345		$	1,678		$	607		$	60

																																															(a)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
																																															(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'												'										'														'										'
			Three Months Ended September 30, 2013																							Nine Months Ended September 30, 2013													Nine Months Ended September 30, 2012
	(in millions)		Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)		Total				Three Months Ended September 30, 2012								(in millions)			Available-for-Sale Auction Rate Securities			Available-for-Sale NDTF Investments			Derivatives (net)			Total		(in millions)		Available-for-Sale Auction Rate Securities		Available-for-Sale NDTF Investments		Derivatives (net)		Total
	Balance at June 30, 2013		$	3		$	71		$	-4	$	70	(in millions)		Available-for-Sale Auction Rate Securities		Available-for-Sale NDTF Investments		Derivatives (net)		Total		Balance at December 31, 2012			$	3		$	69		$	-12		$	60	Balance at December 31, 2011		$	12	$	53	$	―	$	65
	Purchases, sales, issuances and settlements:												Balance at June 30, 2012		$	6	$	64	$	―	$	70	Purchases, sales, issuances and settlements:														Total pretax gains included in other comprehensive income:
		Purchases		―			2			―		2	Purchases, sales, issuances and settlements:											Purchases			―			5			―			5		Gains on available for sale securities and other		2		―		―		2
		Sales		―			-2			―		-2		Purchases		―		1		―		1		Sales			―			-5			―			-5	Purchases, sales, issuances and settlements:
	Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities			―			1			―		1		Issuances		―		―		-14		-14		Settlements			―			―			8			8		Purchases		―		10		―		10
	Balance at September 30, 2013		$	3		$	72		$	-4	$	71		Settlements		―		―		2		2	Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				―			3			―			3		Issuances		―		―		-14		-14
													Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities			―		1		―		1	Balance at September 30, 2013			$	3		$	72		$	-4		$	71		Settlements		-8		―		2		-6
													Balance at September 30, 2012		$	6	$	66	$	-12	$	60	Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013														Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities			―		3		―		3
																								Operating Revenues		$	―		$	―		$	-4		$	-4	Balance at September 30, 2012		$	6	$	66	$	-12	$	60
																							Total			$	―		$	―		$	-4		$	-4

Quantitative Information Table - Level 3	'												'										'														'										'
																									30-Sep-13
																							Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range																		31-Dec-12
																							Duke Energy																								Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
																							Commodity natural gas contracts		$	-43		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.47	-	10.36													Duke Energy
																							FERC mitigation power sale agreements			-4		Discounted cash flow		Forward electricity curves - price per megawatt-hour (MWh)		25.79	-	48.34													Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
																							Financial transmission rights (FTRs)			15		RTO market pricing		FTR price - per MWh		-1.53	-	10.86													FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Commodity power contracts			5		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
																							Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	122.64													Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
																							Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		29.3	-	100.8													Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
																							Reserves			-12				Bid-ask spreads, implied volatility, probability of default																	Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
																							Total Level 3 derivatives		$	-38																					Reserves			-12				Bid-ask spreads, implied volatility, probability of default
																							Duke Energy Carolinas																								Total Level 3 derivatives		$	-85
																							FERC mitigation power sale agreements		$	-4		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	-	48.34													Duke Energy Carolinas
																							Duke Energy Ohio																								FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
																							Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	-0.09	-	0.46													Progress Energy
																							Commodity power contracts			13		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Commodity natural gas contracts			-9		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.47	-	4.55													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Reserves			-11				Bid-ask spreads, implied volatility, probability of default																	Total Level 3 derivatives		$	-38
																							Total Level 3 derivatives		$	-6																					Duke Energy Progress
																							Duke Energy Indiana																								Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Financial transmission rights (FTRs)		$	14		RTO market pricing		FTR price - per MWh	$	-1.53	-	10.86													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Ohio
																																															Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
																																															Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
																																															Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
																																															Reserves			-11				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-6
																																															Duke Energy Indiana
																																															Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

Progress Energy [Member]	'												'										'														'										'
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																										30-Sep-13																								31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Nuclear decommissioning trust fund equity securities			$	1,489		$	1,483		$	6		$	―											Nuclear decommissioning trust fund equity securities			$	1,245		$	1,239		$	6		$	―
																							Nuclear decommissioning trust fund debt securities and other				642			172			470			―											Nuclear decommissioning trust fund debt securities and other				643			162			481			―
																							Other trading and available-for-sale debt securities and other^(a)				55			19			36			―											Other trading and available-for-sale debt securities and other^(a)				57			17			40			―
																								Total assets			2,186			1,674			512			―											Derivative assets^(b)				11			―			11			―
																							Derivative liabilities^(c)				-282			―			-282			―												Total assets			1,956			1,418			538			―
																								Net assets		$	1,904		$	1,674		$	230		$	―											Derivative liabilities^(c)				-440			―			-402			-38
																																																Net assets		$	1,516		$	1,418		$	136		$	-38

																																															(a)	Included in Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
																																															(b)	Included in Other Current Assets within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
																																															(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'												'										'														'										'
			Derivatives (net)
			Three Months Ended September 30,																							Derivatives (net)
	(in millions)				2013			2012																		Nine Months Ended September 30,
	Balance at beginning of period			$	-35		$	-30															(in millions)					2013			2012
	Total pretax realized or unrealized gains included in earnings:																						Balance at beginning of period				$	-38		$	-24
		Revenue: Regulated electric			―			2															Total pretax realized or unrealized gains included in earnings:
	Purchases, sales, issuances and settlements:																							Operating Revenues				―			2
		Issuances			2			-16															Purchases, sales, issuances and settlements:
		Settlements			―			4																Issuances				10			-16
	Total (losses) gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				-1			4																Settlements				―			4
	Transfers in and out of Level 3 due to observability of inputs				34			―															Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					-6			-2
	Balance at end of period			$	―		$	-36															Transfers in and out of Level 3 due to observability of inputs					34			―
																							Balance at end of period				$	―		$	-36
																							Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
																								Revenue: Regulated electric			$	10		$	―
																							Total				$	10		$	―

Quantitative Information Table - Level 3	'												'										'														'										'

																																																	31-Dec-12
																																															Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
																																															Duke Energy
																																															Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
																																															FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
																																															Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
																																															Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
																																															Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
																																															Reserves			-12				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-85
																																															Duke Energy Carolinas
																																															FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
																																															Progress Energy
																																															Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																																															FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Progress
																																															Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																																															FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Ohio
																																															Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
																																															Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
																																															Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
																																															Reserves			-11				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-6
																																															Duke Energy Indiana
																																															Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

Duke Energy Progress [Member]	'												'										'														'										'
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																										30-Sep-13																								31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Nuclear decommissioning trust fund equity securities			$	985		$	985		$	―		$	―											Nuclear decommissioning trust fund equity securities			$	811		$	811		$	―		$	―
																							Nuclear decommissioning trust fund debt securities and other				440			112			328			―											Nuclear decommissioning trust fund debt securities and other				448			119			329			―
																							Other trading and available-for-sale debt securities and other^(a)				2			2			―			―											Other trading and available-for-sale debt securities and other^(a)				3			3			―			―
																								Total assets			1,427			1,099			328			―											Derivative assets^(b)				2			―			2			―
																							Derivative liabilities^(c)				-107			―			-107			―												Total assets			1,264			933			331			―
																								Net assets		$	1,320		$	1,099		$	221		$	―											Derivative liabilities^(c)				-166			―			-128			-38
																																																Net assets		$	1,098		$	933		$	203		$	-38

																																															(a)	Included in Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
																																															(b)	Included in Other Current Assets within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
																																															(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'												'										'														'										'
			Derivatives (net)
			Three Months Ended September 30,																							Derivatives (net)
	(in millions)				2013			2012																		Nine Months Ended September 30,
	Balance at beginning of period			$	-35		$	-28															(in millions)					2013			2012
	Total pretax realized or unrealized gains (losses) included in earnings:																						Balance at beginning of period				$	-38		$	-24
		Operating Revenues			―			2															Total pretax realized or unrealized gains (losses) included in earnings:
	Purchases, sales, issuances and settlements:																							Operating Revenues				―			2
		Issuances						-16															Purchases, sales, issuances and settlements:
		Settlements			2			4																Issuances				9			-16
	Total (losses) gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				-1			2																Settlements				―			4
	Transfers in and out of Level 3 due to observability of inputs				34			―															Total losses included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					-5			-2
	Balance at end of period			$	―		$	-36															Transfers in and out of Level 3 due to observability of inputs					34			―
	Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013																						Balance at end of period				$	―		$	-36
		Revenue: Regulated electric		$	1		$	―															Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013
	Total			$	1		$	―																Revenue: Regulated electric			$	10		$	―
																							Total				$	10		$	―

Quantitative Information Table - Level 3	'												'										'														'										'

																																																	31-Dec-12
																																															Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
																																															Duke Energy
																																															Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
																																															FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
																																															Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
																																															Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
																																															Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
																																															Reserves			-12				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-85
																																															Duke Energy Carolinas
																																															FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
																																															Progress Energy
																																															Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																																															FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Progress
																																															Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																																															FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Ohio
																																															Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
																																															Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
																																															Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
																																															Reserves			-11				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-6
																																															Duke Energy Indiana
																																															Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

Duke Energy Florida [Member]	'												'										'														'										'
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																										30-Sep-13																								31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Nuclear decommissioning trust fund equity securities			$	505		$	499		$	6		$	―											Nuclear decommissioning trust fund equity securities			$	435		$	429		$	6		$	―
																							Nuclear decommissioning trust fund debt securities and other				202			60			142			―											Nuclear decommissioning trust fund debt securities and other				194			43			151			―
																							Other trading and available-for-sale debt securities and other^(a)				39			2			37			―											Other trading and available-for-sale debt securities and other^(a)				43			3			40			―
																								Total assets			746			561			185			―											Derivative assets				9			―			9			―
																							Derivative liabilities^(b)				-171			―			-171			―												Total assets			681			475			206			―
																								Net assets		$	575		$	561		$	14		$	―											Derivative liabilities^(b)				-270			―			-270			―
																																																Net assets (liabilities)		$	411		$	475		$	-64		$	―

																																															(a)	Included in Other within Investments and Other Assets in the Condensed Balance Sheets.
																																															(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Balance Sheets

Duke Energy Ohio [Member]	'												'										'														'										'
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																										30-Sep-13																								31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Derivative assets^(a)			$	70		$	49		$	―		$	21											Derivative assets^(a)			$	59		$	48		$	2		$	9
																							Derivative liabilities^(b)				-46			-14			-5			-27											Derivative liabilities^(b)				-38			-15			-8			-15
																								Net assets (liabilities)		$	24		$	35		$	-5		$	-6												Net assets (liabilities)		$	21		$	33		$	-6		$	-6

																																															(a)	Included in Other within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
																																															(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'												'										'														'										'
			Derivatives (net)
			Three Months Ended September 30,																							Derivatives (net)
	(in millions)				2013			2012																		Nine Months Ended September 30,
	Balance at beginning of period			$	-19		$	-2															(in millions)					2013			2012
	Total pretax realized or unrealized gains (losses) included in earnings:																						Balance at beginning of period				$	-6		$	-3
		Revenue: Regulated electric			―			1															Total pretax realized or unrealized gains (losses) included in earnings:
		Revenue: Nonregulated electric and other			11			-6																Revenue: Regulated electric				―			1
	Purchases, sales, issuances and settlements:																							Revenue: Nonregulated electric and other				-4			-5
		Settlements			2			-1															Purchases, sales, issuances and settlements:
	Balance at end of period			$	-6		$	-8																Purchases				1			―
	Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013:																							Settlements				―			1
		Revenue: Nonregulated electric and other		$	-3		$	―															Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					3			-2
	Total			$	-3		$	―															Balance at end of period				$	-6		$	-8
																							Pretax amounts included in the Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at September 30, 2013:
																								Revenue: Nonregulated electric and other			$	-16		$	1
																							Total				$	-16		$	1

Quantitative Information Table - Level 3	'												'										'														'										'
																									30-Sep-13
																							Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range																		31-Dec-12
																							Duke Energy																								Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
																							Commodity natural gas contracts		$	-43		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.47	-	10.36													Duke Energy
																							FERC mitigation power sale agreements			-4		Discounted cash flow		Forward electricity curves - price per megawatt-hour (MWh)		25.79	-	48.34													Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
																							Financial transmission rights (FTRs)			15		RTO market pricing		FTR price - per MWh		-1.53	-	10.86													FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Commodity power contracts			5		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
																							Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	122.64													Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
																							Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		29.3	-	100.8													Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
																							Reserves			-12				Bid-ask spreads, implied volatility, probability of default																	Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
																							Total Level 3 derivatives		$	-38																					Reserves			-12				Bid-ask spreads, implied volatility, probability of default
																							Duke Energy Carolinas																								Total Level 3 derivatives		$	-85
																							FERC mitigation power sale agreements		$	-4		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	-	48.34													Duke Energy Carolinas
																							Duke Energy Ohio																								FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
																							Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	-0.09	-	0.46													Progress Energy
																							Commodity power contracts			13		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Commodity natural gas contracts			-9		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.47	-	4.55													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Reserves			-11				Bid-ask spreads, implied volatility, probability of default																	Total Level 3 derivatives		$	-38
																							Total Level 3 derivatives		$	-6																					Duke Energy Progress
																							Duke Energy Indiana																								Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Financial transmission rights (FTRs)		$	14		RTO market pricing		FTR price - per MWh	$	-1.53	-	10.86													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Ohio
																																															Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
																																															Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
																																															Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
																																															Reserves			-11				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-6
																																															Duke Energy Indiana
																																															Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

Duke Energy Indiana [Member]	'												'										'														'										'
Fair Value Disclosures [Line Items]	'												'										'														'										'
Fair Value Measurement Amounts For Assets And Liabilities	'												'										'														'										'

																										30-Sep-13																								31-Dec-12
																							(in millions)			Total Fair Value			Level 1			Level 2			Level 3												(in millions)			Total Fair Value			Level 1			Level 2			Level 3
																							Available-for-sale equity securities^(a)			$	60		$	60		$	―		$	―											Available-for-sale equity securities^(a)			$	49		$	49		$	―		$	―
																							Available-for-sale debt securities^(a)				28			―			28			―											Available-for-sale debt securities^(a)				29			―			29			―
																							Derivative assets^(b)				14			―			―			14											Derivative assets^(b)				10			―			―			10
																								Total assets			102			60			28		$	14												Total assets			88			49			29		$	10
																								Net assets (liabilities)		$	102		$	60		$	28		$	14											Derivative liabilities^(c)				-63			―			-63			―
																																																Net assets (liabilities)		$	25		$	49		$	-34		$	10

																																															(a)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
																																															(b)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheets.
																																															(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'												'										'														'										'
			Derivatives (net)
			Three Months Ended September 30,																							Derivatives (net)
	(in millions)				2013			2012																		Nine Months Ended September 30,
	Balance at beginning of period			$	18		$	22															(in millions)					2013			2012
	Total pretax realized or unrealized gains (losses) included in earnings:																						Balance at beginning of period				$	10		$	4
		Operating Revenues			3			11															Total pretax realized or unrealized gains (losses) included in earnings:
	Purchases, sales, issuances and settlements:																							Operating Revenues				5			35
		Settlements			-10			-16															Purchases, sales, issuances and settlements:
	Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities				3			―																Purchases				20			―
	Balance at end of period			$	14		$	17																Sales				―			22
																								Settlements				-23			-45
																							Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities					2			1
																							Balance at end of period				$	14		$	17

Quantitative Information Table - Level 3	'												'										'														'										'
																									30-Sep-13
																							Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range																		31-Dec-12
																							Duke Energy																								Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
																							Commodity natural gas contracts		$	-43		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.47	-	10.36													Duke Energy
																							FERC mitigation power sale agreements			-4		Discounted cash flow		Forward electricity curves - price per megawatt-hour (MWh)		25.79	-	48.34													Commodity natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	-	9.99
																							Financial transmission rights (FTRs)			15		RTO market pricing		FTR price - per MWh		-1.53	-	10.86													FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Commodity power contracts			5		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Financial transmission rights (FTRs)			11		RTO market pricing		FTR price - per MWh		23.63	-	39.22
																							Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	122.64													Commodity power contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
																							Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		29.3	-	100.8													Commodity capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
																							Reserves			-12				Bid-ask spreads, implied volatility, probability of default																	Commodity capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
																							Total Level 3 derivatives		$	-38																					Reserves			-12				Bid-ask spreads, implied volatility, probability of default
																							Duke Energy Carolinas																								Total Level 3 derivatives		$	-85
																							FERC mitigation power sale agreements		$	-4		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	-	48.34													Duke Energy Carolinas
																							Duke Energy Ohio																								FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
																							Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	-0.09	-	0.46													Progress Energy
																							Commodity power contracts			13		Discounted cash flow		Forward electricity curves - price per MWh		26.2	-	54.19													Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Commodity natural gas contracts			-9		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.47	-	4.55													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																							Reserves			-11				Bid-ask spreads, implied volatility, probability of default																	Total Level 3 derivatives		$	-38
																							Total Level 3 derivatives		$	-6																					Duke Energy Progress
																							Duke Energy Indiana																								Commodity natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
																							Financial transmission rights (FTRs)		$	14		RTO market pricing		FTR price - per MWh	$	-1.53	-	10.86													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
																																															Total Level 3 derivatives		$	-38
																																															Duke Energy Ohio
																																															Financial transmission rights (FTRs)		$	1		RTO market pricing		FTR price - per MWh	$	27.17	-	39.22
																																															Commodity power contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
																																															Commodity natural gas contracts			5		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.3	-	4.51
																																															Reserves			-11				Bid-ask spreads, implied volatility, probability of default
																																															Total Level 3 derivatives		$	-6
																																															Duke Energy Indiana
																																															Financial transmission rights (FTRs)		$	10		RTO market pricing		FTR price - per MWh	$	23.63	-	35.43

Investments_in_Debt_and_Equity1

Investments in Debt and Equity Securities (Tables)	9 Months Ended
Investments in Debt and Equity Securities (Tables)	Sep. 30, 2013
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
			30-Sep-13									31-Dec-12
	(in millions)		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses				Estimated Fair Value		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses			Estimated Fair Value
	NDTF
	Cash and cash equivalents			$	―		$	―		$	111		$	―		$	―	$	105
	Equity securities				1,560			13			3,280			1,132			19		2,837
	Corporate debt securities				9			6			323			21			1		338
	Municipal bonds				5			7			213			12			1		194
	U.S. government bonds				14			8			712			24			1		625
	Other debt securities				17			4			167			10			1		164
	Total NDTF				1,605			38			4,806			1,199			23		4,263
	Other Investments
	Cash and cash equivalents				―			―			21			―			―		17
	Equity securities				22			―			83			10			―		63
	Corporate debt securities				1			2			178			2			―		381
	Municipal bonds				2			2			80			4			1		70
	U.S. government bonds				―			―			38			―			―		23
	Other debt securities				―			1			92			1			―		86
	Auction rate securities				―			7			25			―			6		29
	Total Other Investments^(a)				25			12			517			17			7		669
	Total Investments			$	1,630		$	50		$	5,323		$	1,216		$	30	$	4,932

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

Schedule of Maturity Dates for Debt Securities	'
	(in millions)		30-Sep-13
	Due in one year or less			$	185
	Due after one through five years				394
	Due after five through 10 years				434
	Due after 10 years				790
	Total			$	1,803

Schedule of Realized Gain (Loss)	'

			Three Months Ended September 30,						Nine Months Ended September 30,
	(in millions)				2013	2012					2013	2012
	Realized gains			$	72	$	30			$	135	$	80
	Realized losses				16		12				38		14

Duke Energy Carolinas [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
			30-Sep-13									31-Dec-12
	(in millions)		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses				Estimated Fair Value		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses			Estimated Fair Value
	NDTF
	Cash and cash equivalents			$	―		$	―		$	46		$	―		$	―	$	40
	Equity securities				828			5			1,790			600			5		1,592
	Corporate debt securities				4			5			236			11			1		250
	Municipal bonds				―			1			52			2			―		40
	U.S. government bonds				5			4			396			10			―		304
	Other debt securities				17			4			147			9			2		135
	Total NDTF				854			19			2,667			632			8		2,361
	Other Investments
	Auction rate securities				―			1			3			―			1		3
	Total Other Investments^(a)				―			1			3			―			1		3
	Total Investments			$	854		$	20		$	2,670		$	632		$	9	$	2,364

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

Schedule of Maturity Dates for Debt Securities	'
	(in millions)		30-Sep-13
	Due in one year or less			$	23
	Due after one through five years				175
	Due after five through 10 years				223
	Due after 10 years				410
	Total			$	831

Schedule of Realized Gain (Loss)	'

			Three Months Ended September 30,						Nine Months Ended September 30,
	(in millions)				2013	2012					2013	2012
	Realized gains			$	49	$	19			$	95	$	65
	Realized losses				1		5				11		7

Progress Energy [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
			30-Sep-13									31-Dec-12
	(in millions)		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses				Estimated Fair Value		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses			Estimated Fair Value
	NDTF
	Cash and cash equivalents			$	―		$	―		$	65		$	―		$	―	$	65
	Equity securities				732			8			1,490			532			14		1,245
	Corporate debt securities				5			1			87			9			―		89
	Municipal bonds				5			6			161			11			1		154
	U.S. government bonds				9			4			316			14			―		321
	Other debt securities				―			―			20			1			―		28
	Total NDTF				751			19			2,139			567			15		1,902
	Other Investments
	Cash and cash equivalents				―			―			21			―			―		17
	Municipal bonds				1			1			36			3			―		40
	Total Other Investments^(a)				1			1			57			3			―		57
	Total Investments			$	752		$	20		$	2,196		$	570		$	15	$	1,959

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

Schedule of Maturity Dates for Debt Securities	'
	(in millions)		30-Sep-13
	Due in one year or less			$	14
	Due after one through five years				162
	Due after five through 10 years				150
	Due after 10 years				294
	Total			$	620

Schedule of Realized Gain (Loss)	'

			Three Months Ended September 30,						Nine Months Ended September 30,
	(in millions)				2013	2012					2013	2012
	Realized gains			$	22	$	8			$	37	$	23
	Realized losses				11		6				20		12

Duke Energy Progress [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
			30-Sep-13									31-Dec-12
	(in millions)		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses				Estimated Fair Value		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses			Estimated Fair Value
	NDTF
	Cash and cash equivalents			$	―		$	―		$	30		$	―		$	―	$	55
	Equity securities				472			7			985			337			11		811
	Corporate debt securities				5			1			83			8			―		78
	Municipal bonds				2			4			103			4			―		80
	U.S. government bonds				8			3			225			13			―		241
	Other debt securities				―			―			9			1			―		10
	Total NDTF				487			15			1,435			363			11		1,275
	Other Investments
	Cash and cash equivalents				―			―			2			―			―		3
	Total Other Investments^(a)				―			―			2			―			―		3
	Total Investments			$	487		$	15		$	1,437		$	363		$	11	$	1,278

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

Schedule of Maturity Dates for Debt Securities	'
	(in millions)		30-Sep-13
	Due in one year or less			$	6
	Due after one through five years				125
	Due after five through 10 years				88
	Due after 10 years				201
	Total			$	420

Schedule of Realized Gain (Loss)	'

			Three Months Ended September 30,						Nine Months Ended September 30,
	(in millions)				2013	2012					2013	2012
	Realized gains			$	7	$	4			$	15	$	14
	Realized losses				2		2				6		5

Duke Energy Florida [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
			30-Sep-13									31-Dec-12
	(in millions)		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses				Estimated Fair Value		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses			Estimated Fair Value
	NDTF
	Cash and cash equivalents			$	―		$	―		$	35		$	―		$	―	$	10
	Equity securities				260			1			505			194			4		434
	Corporate debt securities				―			―			4			1			―		11
	Municipal bonds				3			2			58			7			―		74
	U.S. government bonds				1			1			91			1			―		80
	Other debt securities				―			―			11			1			―		18
	Total NDTF				264			4			704			204			4		627
	Other Investments
	Cash and cash equivalents				―			―			4			―			―		1
	Municipal bonds				1			1			37			3			―		40
	Total Other Investments^(a)				1			1			41			3			―		41
	Total Investments			$	265		$	5		$	745		$	207		$	4	$	668

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Balance Sheets.

Schedule of Maturity Dates for Debt Securities	'
	(in millions)		30-Sep-13
	Due in one year or less			$	8
	Due after one through five years				37
	Due after five through 10 years				62
	Due after 10 years				94
	Total			$	201

Schedule of Realized Gain (Loss)	'
			Three Months Ended September 30,						Nine Months Ended September 30,
	(in millions)				2013	2012					2013		2012
	Realized gains			$	14	$	4			$	22	$	9
	Realized losses				9		4				13		7

Duke Energy Indiana [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
			30-Sep-13									31-Dec-12
	(in millions)		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses				Estimated Fair Value		Gross Unrealized Holding Gains			Gross Unrealized Holding Losses			Estimated Fair Value
	Other Investments
	Equity securities			$	19		$	―		$	60		$	9		$	―	$	50
	Municipal bonds				―			1			28			1			―		28
	Total Other Investments^(a)				19			1			88			10			―		78
	Total Investments			$	19		$	1		$	88		$	10		$	―	$	78

	(a)	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

Schedule of Maturity Dates for Debt Securities	'
	(in millions)		30-Sep-13
	Due in one year or less			$	2
	Due after one through five years				21
	Due after five through 10 years				4
	Due after 10 years				1
	Total			$	28

Variable_Interest_Entities_Tab

Variable Interest Entities (Tables)	3 Months Ended											9 Months Ended																		12 Months Ended
Variable Interest Entities (Tables)	Sep. 30, 2013											Sep. 30, 2013																		Dec. 31, 2012
Variable Interest Entity [Line Items]	'											'																		'
Schedule Of Consolidated VIEs	'											'																		'

															30-Sep-13																	31-Dec-12
												(in millions)			DERF^(a)			CRC		CinCapV		Renewables				Other		Total		(in millions)		DERF			CRC		CinCapV		Renewables			Other		Total
												ASSETS																		ASSETS
												Current Assets																		Current Assets
												Restricted receivables of variable interest entities				703			527		17			11			―		1,258	Restricted receivables of variable interest entities		$	637		$	534	$	15		$	16	$	-1	$	1,201
												Other				―			―		5			199			2		206	Other			―			―		4			133		2		139
												Investments and Other Assets																		Investments and Other Assets
												Intangibles, net				―			―		―			11			―		11	Intangibles, net			―			―		―			12		―		12
												Restricted other assets of variable interest entities				―			―		40			12			―		52	Restricted other assets of variable interest entities			―			―		52			2		―		54
												Other				―			―		12			4			3		19	Other			―			―		10			―		2		12
												Property, Plant and Equipment																		Property, Plant and Equipment
												Property, Plant and Equipment, Cost				―			―		―			1,663			16		1,679	Property, Plant and Equipment, Cost			―			―		―			1,543		15		1,558
												Accumulated depreciation and amortization				―			―		―			-146			-5		-151	Accumulated depreciation and amortization			―			―		―			-98		-5		-103
												Regulatory Assets and Deferred Debits																		Regulatory Assets and Deferred Debits
												Other				―			―		―			34			―		34	Other			―			―		―			40		―		40
													Total Assets			703			527		74			1,788			16		3,108		Total Assets		637			534		81			1,648		13		2,913
												LIABILITIES AND EQUITY																		LIABILITIES AND EQUITY
												Current Liabilities																		Current Liabilities
												Accounts payable				―			―		―			3			―		3	Accounts payable			―			―		―			1		―		1
												Non-recourse notes payable of variable interest entities				―			325		―			―			―		325	Non-recourse notes payable of variable interest entities			―			312		―			―		―		312
												Taxes accrued				―			―		―			12			―		12	Taxes accrued			―			―		―			62		―		62
												Current maturities of long-term debt				―			―		14			62			―		76	Current maturities of long-term debt			―			―		13			459		―		472
												Other				―			―		5			26			―		31	Other			―			―		4			25		―		29
												Non-recourse Long-term Debt of variable interest entities				300			―		37			928			―		1,265	Non-recourse Long-term Debt of variable interest entities			300			―		48			504		―		852
												Deferred income taxes				―			―		―			255			―		255	Deferred income taxes			―			―		―			154		―		154
												Asset retirement obligations				―			―		―			25			―		25	Asset retirement obligations			―			―		―			23		―		23
												Other				―			―		12			102			―		114	Other			―			―		10			39		―		49
													Total Liabilities			300			325		68			1,413			―		2,106		Total Liabilities		300			312		75			1,267		―		1,954
												Net Assets of Consolidated Variable Interest Entities			$	403		$	202	$	6		$	375		$	16	$	1,002	Net Assets of Consolidated Variable Interest Entities		$	337		$	222	$	6		$	381	$	13	$	959

												(a)	Duke Energy Receivables Finance Company, LLC (DERF) is a wholly owned limited liability company of Duke Energy Carolinas.

Schedule Of Non-Consolidated VIEs	'											'																		'

															30-Sep-13																	31-Dec-12
																Duke Energy										Duke Energy Ohio		Duke Energy Indiana				Duke Energy												Duke Energy Ohio		Duke Energy Indiana
												(in millions)			DukeNet		Renewables			Other			Total			Duke Energy Ohio		Duke Energy Indiana		(in millions)		DukeNet		Renewables			FPC Capital I Trust^(a)			Other		Total		Duke Energy Ohio		Duke Energy Indiana
												Receivables			$	―		$	―	$	―		$	―		$	75	$	114	Receivables		$	―		$	―	$	―		$	―	$	―	$	97	$	116
												Investments in equity method unconsolidated affiliates				113			152		25			290			―		―	Investments in equity method unconsolidated affiliates			118			147		―			27		292		―		―
												Intangibles, net				―			―		100			100			98		―	Intangibles, net			―			―		―			104		104		104		―
												Investments and other assets				―			―		4			4			―		―	Investments and other assets			―			―		9			2		11		―		―
													Total assets			113			152		129			394			173		114		Total assets		118			147		9			133		407		201		116
												Other current liabilities				―			―		2			2			―		―	Other current liabilities			―			―		―			3		3		―		―
												Deferred credits and other liabilities				―			―		15			15			―		―	Deferred credits and other liabilities			―			―		319			17		336		―		―
													Total liabilities			―			―		17			17			―		―		Total liabilities		―			―		319			20		339		―		―
												Net assets			$	113		$	152	$	112		$	377		$	173	$	114	Net assets (liabilities)		$	118		$	147	$	-310		$	113	$	68	$	201	$	116

																														(a)	The entire balance of Investments and other assets and $274 million of the Deferred credits and other liabilities balance applies to Progress Energy.

Progress Energy [Member]	'											'																		'
Variable Interest Entity [Line Items]	'											'																		'
Schedule Of Non-Consolidated VIEs	'											'																		'

																																31-Dec-12
																																Duke Energy												Duke Energy Ohio		Duke Energy Indiana
																														(in millions)		DukeNet		Renewables			FPC Capital I Trust^(a)			Other		Total		Duke Energy Ohio		Duke Energy Indiana
																														Receivables		$	―		$	―	$	―		$	―	$	―	$	97	$	116
																														Investments in equity method unconsolidated affiliates			118			147		―			27		292		―		―
																														Intangibles, net			―			―		―			104		104		104		―
																														Investments and other assets			―			―		9			2		11		―		―
																															Total assets		118			147		9			133		407		201		116
																														Other current liabilities			―			―		―			3		3		―		―
																														Deferred credits and other liabilities			―			―		319			17		336		―		―
																															Total liabilities		―			―		319			20		339		―		―
																														Net assets (liabilities)		$	118		$	147	$	-310		$	113	$	68	$	201	$	116

																														(a)	The entire balance of Investments and other assets and $274 million of the Deferred credits and other liabilities balance applies to Progress Energy.

Duke Energy Ohio [Member]	'											'																		'
Variable Interest Entity [Line Items]	'											'																		'
Schedule Of Non-Consolidated VIEs	'											'																		'

															30-Sep-13																	31-Dec-12
																Duke Energy										Duke Energy Ohio		Duke Energy Indiana				Duke Energy												Duke Energy Ohio		Duke Energy Indiana
												(in millions)			DukeNet		Renewables			Other			Total			Duke Energy Ohio		Duke Energy Indiana		(in millions)		DukeNet		Renewables			FPC Capital I Trust^(a)			Other		Total		Duke Energy Ohio		Duke Energy Indiana
												Receivables			$	―		$	―	$	―		$	―		$	75	$	114	Receivables		$	―		$	―	$	―		$	―	$	―	$	97	$	116
												Investments in equity method unconsolidated affiliates				113			152		25			290			―		―	Investments in equity method unconsolidated affiliates			118			147		―			27		292		―		―
												Intangibles, net				―			―		100			100			98		―	Intangibles, net			―			―		―			104		104		104		―
												Investments and other assets				―			―		4			4			―		―	Investments and other assets			―			―		9			2		11		―		―
													Total assets			113			152		129			394			173		114		Total assets		118			147		9			133		407		201		116
												Other current liabilities				―			―		2			2			―		―	Other current liabilities			―			―		―			3		3		―		―
												Deferred credits and other liabilities				―			―		15			15			―		―	Deferred credits and other liabilities			―			―		319			17		336		―		―
													Total liabilities			―			―		17			17			―		―		Total liabilities		―			―		319			20		339		―		―
												Net assets			$	113		$	152	$	112		$	377		$	173	$	114	Net assets (liabilities)		$	118		$	147	$	-310		$	113	$	68	$	201	$	116

																														(a)	The entire balance of Investments and other assets and $274 million of the Deferred credits and other liabilities balance applies to Progress Energy.

CRC Fair Value Assumptions	'											'																		'

															Duke Energy Ohio					Duke Energy Indiana
															2013			2012		2013			2012
												Anticipated credit loss ratio			0.6	%		0.7	%	0.3	%		0.3	%
												Discount rate			1.2	%		1.2	%	1.2	%		1.2	%
												Receivable turnover rate			12.8	%		12.7	%	10.3	%		10.2	%

CRC Receivables Sold	'											'																		'
														Duke Energy Ohio						Duke Energy Indiana
												(in millions)		30-Sep-13			31-Dec-12			30-Sep-13			31-Dec-12
												Receivables sold			$	235		$	282		$	332		$	289
												Less: Retained interests				75			97			114			116
												Net receivables sold			$	160		$	185		$	218		$	173

CRC Sales and Cash Flows	'											'																		'
		Duke Energy Ohio					Duke Energy Indiana							Duke Energy Ohio						Duke Energy Indiana
		Three Months Ended September 30,					Three Months Ended September 30,							Nine Months Ended September 30,						Nine Months Ended September 30,
	(in millions)		2013		2012			2013		2012		(in millions)		2013				2012		2013				2012
	Sales											Sales
	Receivables sold		$	514	$	518		$	765	$	711	Receivables sold			$	1,664		$	1,618		$	2,214		$	2,118
	Loss recognized on sale			3		3			2		3	Loss recognized on sale				9			10			8			9
	Cash flows											Cash flows
	Cash proceeds from receivables sold			518		531			758		733	Cash proceeds from receivables sold				1,674			1,651			2,204			2,130
	Collection fees received			―		―			―		―	Collection fees received				1			1			1			1
	Return received on retained interests			1		1			2		2	Return received on retained interests				4			4			5			5

Duke Energy Indiana [Member]	'											'																		'
Variable Interest Entity [Line Items]	'											'																		'
Schedule Of Non-Consolidated VIEs	'											'																		'

															30-Sep-13																	31-Dec-12
																Duke Energy										Duke Energy Ohio		Duke Energy Indiana				Duke Energy												Duke Energy Ohio		Duke Energy Indiana
												(in millions)			DukeNet		Renewables			Other			Total			Duke Energy Ohio		Duke Energy Indiana		(in millions)		DukeNet		Renewables			FPC Capital I Trust^(a)			Other		Total		Duke Energy Ohio		Duke Energy Indiana
												Receivables			$	―		$	―	$	―		$	―		$	75	$	114	Receivables		$	―		$	―	$	―		$	―	$	―	$	97	$	116
												Investments in equity method unconsolidated affiliates				113			152		25			290			―		―	Investments in equity method unconsolidated affiliates			118			147		―			27		292		―		―
												Intangibles, net				―			―		100			100			98		―	Intangibles, net			―			―		―			104		104		104		―
												Investments and other assets				―			―		4			4			―		―	Investments and other assets			―			―		9			2		11		―		―
													Total assets			113			152		129			394			173		114		Total assets		118			147		9			133		407		201		116
												Other current liabilities				―			―		2			2			―		―	Other current liabilities			―			―		―			3		3		―		―
												Deferred credits and other liabilities				―			―		15			15			―		―	Deferred credits and other liabilities			―			―		319			17		336		―		―
													Total liabilities			―			―		17			17			―		―		Total liabilities		―			―		319			20		339		―		―
												Net assets			$	113		$	152	$	112		$	377		$	173	$	114	Net assets (liabilities)		$	118		$	147	$	-310		$	113	$	68	$	201	$	116

																														(a)	The entire balance of Investments and other assets and $274 million of the Deferred credits and other liabilities balance applies to Progress Energy.

CRC Fair Value Assumptions	'											'																		'

															Duke Energy Ohio					Duke Energy Indiana
															2013			2012		2013			2012
												Anticipated credit loss ratio			0.6	%		0.7	%	0.3	%		0.3	%
												Discount rate			1.2	%		1.2	%	1.2	%		1.2	%
												Receivable turnover rate			12.8	%		12.7	%	10.3	%		10.2	%

CRC Receivables Sold	'											'																		'
														Duke Energy Ohio						Duke Energy Indiana
												(in millions)		30-Sep-13			31-Dec-12			30-Sep-13			31-Dec-12
												Receivables sold			$	235		$	282		$	332		$	289
												Less: Retained interests				75			97			114			116
												Net receivables sold			$	160		$	185		$	218		$	173

CRC Sales and Cash Flows	'											'																		'
		Duke Energy Ohio					Duke Energy Indiana							Duke Energy Ohio						Duke Energy Indiana
		Three Months Ended September 30,					Three Months Ended September 30,							Nine Months Ended September 30,						Nine Months Ended September 30,
	(in millions)		2013		2012			2013		2012		(in millions)		2013				2012		2013				2012
	Sales											Sales
	Receivables sold		$	514	$	518		$	765	$	711	Receivables sold			$	1,664		$	1,618		$	2,214		$	2,118
	Loss recognized on sale			3		3			2		3	Loss recognized on sale				9			10			8			9
	Cash flows											Cash flows
	Cash proceeds from receivables sold			518		531			758		733	Cash proceeds from receivables sold				1,674			1,651			2,204			2,130
	Collection fees received			―		―			―		―	Collection fees received				1			1			1			1
	Return received on retained interests			1		1			2		2	Return received on retained interests				4			4			5			5

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	3 Months Ended							9 Months Ended
Earnings Per Share (Tables)	Sep. 30, 2013							Sep. 30, 2013
Earnings Per Share [Line Items]	'							'
Schedule Of Earnings Per Share	'							'

	(In millions, except per-share amounts)	Income		Average Shares			EPS	(In millions, except per-share amounts)	Income		Average Shares			EPS
	Three Months Ended September 30, 2013							Nine Months Ended September 30, 2013
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	989		706	$	1.4	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	1,959		706	$	2.78
	Three Months Ended September 30, 2012							Nine Months Ended September 30, 2012
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	589		699	$	0.84	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	1,326		531	$	2.5

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	9 Months Ended
Stock-Based Compensation (Tables)	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule Of Stock-Based Compensation Expense	'

		Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)			2013		2012			2013		2012
	Stock options		$	―	$	―		$	2	$	2
	Restricted stock unit awards			10		16			36		30
	Performance awards			7		16			25		19
	Total		$	17	$	32		$	63	$	51
	Tax benefit associated with stock-based compensation expense		$	6	$	13		$	24	$	20
	Stock-based compensation costs capitalized			1		―			3		1

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	3 Months Ended																															9 Months Ended
Employee Benefit Plans (Tables)	Sep. 30, 2013															Sep. 30, 2012																Sep. 30, 2013																			Sep. 30, 2012
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Employee Savings Plan Contributions	'															'																'																			'

																																	Three Months Ended September 30,							Nine Months Ended September 30,
																																(in millions)			2013			2012				2013			2012
																																Duke Energy		$	30		$	30			$	101		$	77
																																Duke Energy Carolinas			10			8				34			28
																																Progress Energy			12			12				34			35
																																Duke Energy Progress			7			7				19			18
																																Duke Energy Florida			4			4				11			11
																																Duke Energy Ohio			―			1				2			3
																																Duke Energy Indiana			2			2				5			5

Qualified Pension Plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
		Three Months Ended September 30, 2013																Three Months Ended September 30, 2012															Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Service cost	$	41	$	12	$	15	$	6	$	8	$	1	$	2	Service cost		$	39	$	9	$	16	$	6	$	8	$	2	$	2	Service cost	$	125		$	37		$	45		$	17		$	23	$	4	$	8	Service cost		$	84	$	26	$	47	$	19	$	22	$	5	$	7
	Interest cost on projected benefit obligation		80		20		29		13		13		5		7	Interest cost on projected benefit obligation			94		23		32		15		14		7		8	Interest cost on projected benefit obligation		240			60			87			38			40		16		21	Interest cost on projected benefit obligation			214		68		95		43		42		23		23
	Expected return on plan assets		-137		-37		-50		-24		-21		-7		-11	Expected return on plan assets			-142		-36		-48		-25		-21		-11		-12	Expected return on plan assets		-411			-111			-149			-71			-65		-22		-33	Expected return on plan assets			-330		-109		-141		-72		-61		-33		-35
	Amortization of prior service credit		-2		-2		-1		-1		-1		―		―	Amortization of prior service cost			3		―		2		2		―		―		1	Amortization of prior service credit		-8			-5			-3			-1			-2		―		―	Amortization of prior service cost			6		1		7		6		―		―		2
	Amortization of actuarial loss		61		15		26		11		12		3		6	Amortization of actuarial loss			47		11		24		9		13		2		3	Amortization of actuarial loss		183			45			76			34			37		9		17	Amortization of actuarial loss			96		34		69		28		36		7		10
	Other		2		1		―		1		―		―		1	Other			2		―		1		1		―		―		―	Other		5			2			1			1			―		―		1	Other			4		1		1		1		―		―		―
	Net periodic pension costs^(a)(b)	$	45	$	9	$	19	$	6	$	11	$	2	$	5	Net periodic pension costs^(a)(b)		$	43	$	7	$	27	$	8	$	14	$	―	$	2	Net periodic pension costs^(a)(b)	$	134		$	28		$	57		$	18		$	33	$	7	$	14	Net periodic pension costs^(a)(b)		$	74	$	21	$	78	$	25	$	39	$	2	$	7

																(a)	Duke Energy amounts exclude $3 million for each of the three months ended September 30, 2013 and 2012, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.																																		(a)	Duke Energy amounts exclude $9 million and $10 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.
																(b)	Duke Energy Ohio amounts exclude $1 million and $2 million for the three months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.																																		(b)	Duke Energy Ohio amounts exclude $4 million and $5 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.

Non-Qualified Pension Plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
		Three Months Ended September 30, 2013																Three Months Ended September 30, 2012															Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida
	Service cost	$	1	$	―	$	1	$	1	$	―					Interest cost on projected benefit obligation		$	5	$	―	$	2	$	1	$	1					Service cost	$	2		$	―		$	1		$	1		$	―					Service cost		$	1	$	―	$	1	$	1	$	―
	Interest cost on projected benefit obligation		3		―		1		―		―					Amortization of actuarial loss			1		―		1		―		―					Interest cost on projected benefit obligation		10			1			5			1			1					Interest cost on projected benefit obligation			8		1		6		1		2
	Amortization of actuarial loss		1		―		1		1		1					Net periodic pension costs		$	6	$	―	$	3	$	1	$	1					Amortization of actuarial loss		4			―			3			1			1					Amortization of actuarial loss			2		―		3		1		―
	Net periodic pension costs	$	5	$	―	$	3	$	2	$	1																					Amortization of prior service credit		-1			―			-1			―			―					Amortization of prior service cost			1		―		―		―		―
																																Net periodic pension costs	$	15		$	1		$	8		$	3		$	2					Net periodic pension costs		$	12	$	1	$	10	$	3	$	2

Other Post-Retirement Benefit plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
		Three Months Ended September 30, 2013																Three Months Ended September 30, 2012															Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Service cost	$	7	$	1	$	6	$	3	$	2	$	―	$	1	Service cost		$	7	$	1	$	5	$	2	$	2	$	1	$	1	Service cost	$	21		$	2		$	17		$	9		$	6	$	―	$	1	Service cost		$	10	$	2	$	12	$	6	$	5	$	1	$	1
	Interest cost on accumulated post-retirement benefit obligation		19		3		12		7		5		―		1	Interest cost on accumulated post-retirement benefit obligation			19		4		11		6		4		1		1	Interest cost on accumulated post-retirement benefit obligation		55			9			35			19			13		1		4	Interest cost on accumulated post-retirement benefit obligation			36		12		32		17		13		2		5
	Expected return on plan assets		-4		-2		―		―		―		―		-1	Expected return on plan assets			-4		-3		―		―		―		-1		―	Expected return on plan assets		-11			-7			―			―			―		―		-1	Expected return on plan assets			-12		-8		-1		―		-1		-1		-1
	Amortization of prior service credit		-3		-2		―		―		―		―		―	Amortization of prior service credit			-2		-2		―		―		―		―		―	Amortization of prior service credit		-9			-6			-1			-1			―		―		―	Amortization of prior service credit			-6		-4		―		―		―		―		1
	Amortization of actuarial loss		13		―		13		8		4		―		1	Amortization of net transition liability			3		2		1		―		1		―		―	Amortization of actuarial loss (gain)		39			2			42			26			12		-1		1	Amortization of net transition liability			7		5		3		―		2		―		―
	Net periodic other post-retirement benefit costs^(a)	$	32	$	―	$	31	$	18	$	11	$	―	$	2	Amortization of actuarial loss (gain)			8		1		10		6		3		-1		―	Net periodic other post-retirement benefit costs^(a)(b)	$	95		$	―		$	93		$	53		$	31	$	―	$	5	Amortization of actuarial loss (gain)			5		2		25		14		9		-2		-1
																Special termination charge			9		1		5		2		1		―		―																				Special termination charge			9		1		5		2		1		―		―
																Net periodic other post-retirement benefit costs^(a)		$	40	$	4	$	32	$	16	$	11	$	―	$	2																				Net periodic other post-retirement benefit costs^(a)(b)		$	49	$	10	$	76	$	39	$	29	$	―	$	5

																(a)	Duke Energy amounts exclude $2 million and $3 million for the three months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.																																		(a)	Duke Energy amounts exclude $6 million and $7 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.
																																																			(b)	Duke Energy Ohio amounts exclude $1 million for each of the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy.

Remeasurement of Accumulated Other Post-retirement Benefit Obligation	'															'																'																			'

																																(in millions)
																																Duke Energy		$	551
																																Progress Energy			551
																																Duke Energy Progress			382
																																Duke Energy Florida			103

Duke Energy Carolinas [Member] \| Non-Qualified Pension Plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
																																	Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
																																(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida
																																Service cost	$	2		$	―		$	1		$	1		$	―					Service cost		$	1	$	―	$	1	$	1	$	―
																																Interest cost on projected benefit obligation		10			1			5			1			1					Interest cost on projected benefit obligation			8		1		6		1		2
																																Amortization of actuarial loss		4			―			3			1			1					Amortization of actuarial loss			2		―		3		1		―
																																Amortization of prior service credit		-1			―			-1			―			―					Amortization of prior service cost			1		―		―		―		―
																																Net periodic pension costs	$	15		$	1		$	8		$	3		$	2					Net periodic pension costs		$	12	$	1	$	10	$	3	$	2

Duke Energy Carolinas [Member] \| Other Post-Retirement Benefit plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
																		Three Months Ended September 30, 2013
																(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
																Service cost		$	7	$	1	$	6	$	3	$	2	$	―	$	1
																Interest cost on accumulated post-retirement benefit obligation			19		3		12		7		5		―		1
																Expected return on plan assets			-4		-2		―		―		―		―		-1
																Amortization of prior service credit			-3		-2		―		―		―		―		―
																Amortization of actuarial loss			13		―		13		8		4		―		1
																Net periodic other post-retirement benefit costs^(a)		$	32	$	―	$	31	$	18	$	11	$	―	$	2

Progress Energy [Member] \| Non-Qualified Pension Plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
		Three Months Ended September 30, 2013																Three Months Ended September 30, 2012															Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida
	Service cost	$	1	$	―	$	1	$	1	$	―					Interest cost on projected benefit obligation		$	5	$	―	$	2	$	1	$	1					Service cost	$	2		$	―		$	1		$	1		$	―					Service cost		$	1	$	―	$	1	$	1	$	―
	Interest cost on projected benefit obligation		3		―		1		―		―					Amortization of actuarial loss			1		―		1		―		―					Interest cost on projected benefit obligation		10			1			5			1			1					Interest cost on projected benefit obligation			8		1		6		1		2
	Amortization of actuarial loss		1		―		1		1		1					Net periodic pension costs		$	6	$	―	$	3	$	1	$	1					Amortization of actuarial loss		4			―			3			1			1					Amortization of actuarial loss			2		―		3		1		―
	Net periodic pension costs	$	5	$	―	$	3	$	2	$	1																					Amortization of prior service credit		-1			―			-1			―			―					Amortization of prior service cost			1		―		―		―		―
																																Net periodic pension costs	$	15		$	1		$	8		$	3		$	2					Net periodic pension costs		$	12	$	1	$	10	$	3	$	2

Progress Energy [Member] \| Other Post-Retirement Benefit plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
																		Three Months Ended September 30, 2013
																(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
																Service cost		$	7	$	1	$	6	$	3	$	2	$	―	$	1
																Interest cost on accumulated post-retirement benefit obligation			19		3		12		7		5		―		1
																Expected return on plan assets			-4		-2		―		―		―		―		-1
																Amortization of prior service credit			-3		-2		―		―		―		―		―
																Amortization of actuarial loss			13		―		13		8		4		―		1
																Net periodic other post-retirement benefit costs^(a)		$	32	$	―	$	31	$	18	$	11	$	―	$	2

Remeasurement of Accumulated Other Post-retirement Benefit Obligation	'															'																'																			'

																																(in millions)
																																Duke Energy		$	551
																																Progress Energy			551
																																Duke Energy Progress			382
																																Duke Energy Florida			103

Duke Energy Progress [Member] \| Non-Qualified Pension Plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
		Three Months Ended September 30, 2013																Three Months Ended September 30, 2012															Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida
	Service cost	$	1	$	―	$	1	$	1	$	―					Interest cost on projected benefit obligation		$	5	$	―	$	2	$	1	$	1					Service cost	$	2		$	―		$	1		$	1		$	―					Service cost		$	1	$	―	$	1	$	1	$	―
	Interest cost on projected benefit obligation		3		―		1		―		―					Amortization of actuarial loss			1		―		1		―		―					Interest cost on projected benefit obligation		10			1			5			1			1					Interest cost on projected benefit obligation			8		1		6		1		2
	Amortization of actuarial loss		1		―		1		1		1					Net periodic pension costs		$	6	$	―	$	3	$	1	$	1					Amortization of actuarial loss		4			―			3			1			1					Amortization of actuarial loss			2		―		3		1		―
	Net periodic pension costs	$	5	$	―	$	3	$	2	$	1																					Amortization of prior service credit		-1			―			-1			―			―					Amortization of prior service cost			1		―		―		―		―
																																Net periodic pension costs	$	15		$	1		$	8		$	3		$	2					Net periodic pension costs		$	12	$	1	$	10	$	3	$	2

Duke Energy Progress [Member] \| Other Post-Retirement Benefit plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
																		Three Months Ended September 30, 2013
																(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
																Service cost		$	7	$	1	$	6	$	3	$	2	$	―	$	1
																Interest cost on accumulated post-retirement benefit obligation			19		3		12		7		5		―		1
																Expected return on plan assets			-4		-2		―		―		―		―		-1
																Amortization of prior service credit			-3		-2		―		―		―		―		―
																Amortization of actuarial loss			13		―		13		8		4		―		1
																Net periodic other post-retirement benefit costs^(a)		$	32	$	―	$	31	$	18	$	11	$	―	$	2

Remeasurement of Accumulated Other Post-retirement Benefit Obligation	'															'																'																			'

																																(in millions)
																																Duke Energy		$	551
																																Progress Energy			551
																																Duke Energy Progress			382
																																Duke Energy Florida			103

Duke Energy Florida [Member] \| Non-Qualified Pension Plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
		Three Months Ended September 30, 2013																Three Months Ended September 30, 2012															Nine Months Ended September 30, 2013																				Nine Months Ended September 30, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida						(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida						(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida
	Service cost	$	1	$	―	$	1	$	1	$	―					Interest cost on projected benefit obligation		$	5	$	―	$	2	$	1	$	1					Service cost	$	2		$	―		$	1		$	1		$	―					Service cost		$	1	$	―	$	1	$	1	$	―
	Interest cost on projected benefit obligation		3		―		1		―		―					Amortization of actuarial loss			1		―		1		―		―					Interest cost on projected benefit obligation		10			1			5			1			1					Interest cost on projected benefit obligation			8		1		6		1		2
	Amortization of actuarial loss		1		―		1		1		1					Net periodic pension costs		$	6	$	―	$	3	$	1	$	1					Amortization of actuarial loss		4			―			3			1			1					Amortization of actuarial loss			2		―		3		1		―
	Net periodic pension costs	$	5	$	―	$	3	$	2	$	1																					Amortization of prior service credit		-1			―			-1			―			―					Amortization of prior service cost			1		―		―		―		―
																																Net periodic pension costs	$	15		$	1		$	8		$	3		$	2					Net periodic pension costs		$	12	$	1	$	10	$	3	$	2

Duke Energy Florida [Member] \| Other Post-Retirement Benefit plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
																		Three Months Ended September 30, 2013
																(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
																Service cost		$	7	$	1	$	6	$	3	$	2	$	―	$	1
																Interest cost on accumulated post-retirement benefit obligation			19		3		12		7		5		―		1
																Expected return on plan assets			-4		-2		―		―		―		―		-1
																Amortization of prior service credit			-3		-2		―		―		―		―		―
																Amortization of actuarial loss			13		―		13		8		4		―		1
																Net periodic other post-retirement benefit costs^(a)		$	32	$	―	$	31	$	18	$	11	$	―	$	2

Remeasurement of Accumulated Other Post-retirement Benefit Obligation	'															'																'																			'

																																(in millions)
																																Duke Energy		$	551
																																Progress Energy			551
																																Duke Energy Progress			382
																																Duke Energy Florida			103

Duke Energy Indiana [Member] \| Other Post-Retirement Benefit plans [Member]	'															'																'																			'
Defined Benefit Plan Disclosure [Line Items]	'															'																'																			'
Components of Net Periodic Pension Costs	'															'																'																			'
																		Three Months Ended September 30, 2013
																(in millions)		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
																Service cost		$	7	$	1	$	6	$	3	$	2	$	―	$	1
																Interest cost on accumulated post-retirement benefit obligation			19		3		12		7		5		―		1
																Expected return on plan assets			-4		-2		―		―		―		―		-1
																Amortization of prior service credit			-3		-2		―		―		―		―		―
																Amortization of actuarial loss			13		―		13		8		4		―		1
																Net periodic other post-retirement benefit costs^(a)		$	32	$	―	$	31	$	18	$	11	$	―	$	2

Severance_Tables

Severance (Tables)	9 Months Ended
Severance (Tables)	Sep. 30, 2013
Restructuring Cost and Reserve [Line Items]	'
Schedule of Severance Liability	'

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
	Balance at December 31, 2012		$	135		$	12		$	43		$	23		$	6
	Provision / Adjustments^(a)			41			2			45			7			30
	Cash Reductions			-114			-12			-42			-17			-13
	Balance at September 30, 2013		$	62		$	2		$	46		$	13		$	23

	(a)	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Schedule of Severance Expense	'

			Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)				2013			2012				2013			2012
	Duke Energy			$	5		$	146			$	30		$	146
	Duke Energy Carolinas				—			48				7			48
	Progress Energy				4			66				17			66
	Duke Energy Progress				3			42				12			42
	Duke Energy Florida				1			24				5			24
	Duke Energy Ohio				—			15				2			15
	Duke Energy Indiana				—			13				2			13

Duke Energy Carolinas [Member]	'
Restructuring Cost and Reserve [Line Items]	'
Schedule of Severance Liability	'

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
	Balance at December 31, 2012		$	135		$	12		$	43		$	23		$	6
	Provision / Adjustments^(a)			41			2			45			7			30
	Cash Reductions			-114			-12			-42			-17			-13
	Balance at September 30, 2013		$	62		$	2		$	46		$	13		$	23

	(a)	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Progress Energy [Member]	'
Restructuring Cost and Reserve [Line Items]	'
Schedule of Severance Liability	'

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
	Balance at December 31, 2012		$	135		$	12		$	43		$	23		$	6
	Provision / Adjustments^(a)			41			2			45			7			30
	Cash Reductions			-114			-12			-42			-17			-13
	Balance at September 30, 2013		$	62		$	2		$	46		$	13		$	23

	(a)	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Duke Energy Progress [Member]	'
Restructuring Cost and Reserve [Line Items]	'
Schedule of Severance Liability	'

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
	Balance at December 31, 2012		$	135		$	12		$	43		$	23		$	6
	Provision / Adjustments^(a)			41			2			45			7			30
	Cash Reductions			-114			-12			-42			-17			-13
	Balance at September 30, 2013		$	62		$	2		$	46		$	13		$	23

	(a)	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Duke Energy Florida [Member]	'
Restructuring Cost and Reserve [Line Items]	'
Schedule of Severance Liability	'

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida
	Balance at December 31, 2012		$	135		$	12		$	43		$	23		$	6
	Provision / Adjustments^(a)			41			2			45			7			30
	Cash Reductions			-114			-12			-42			-17			-13
	Balance at September 30, 2013		$	62		$	2		$	46		$	13		$	23

	(a)	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Income_Taxes_and_Other_Taxes_T

Income Taxes and Other Taxes (Tables)	9 Months Ended
Income Taxes and Other Taxes (Tables)	Sep. 30, 2013
Income Tax Disclosure [Line Items]	'
Summary of Effective Tax Rates	'

			Three Months Ended September 30,							Nine Months Ended September 30,
				2013			2012				2013			2012
	Duke Energy			31.5	%		29.4	%			32.6	%		29.6	%
	Duke Energy Carolinas			37.9	%		34.2	%			37.5	%		35.8	%
	Progress Energy			38.8	%		32.8	%			38.1	%		34.7	%
	Duke Energy Progress			35.7	%		31.9	%			37.3	%		31.6	%
	Duke Energy Florida			40	%		35.9	%			40	%		36.9	%
	Duke Energy Ohio			42.9	%		45.2	%			40.4	%		38.9	%
	Duke Energy Indiana			36.6	%		55.1	%			37.2	%		47.7	%

Schedule of Unrecognized Tax Benefits	'

			Nine Months Ended September 30, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Unrecognized tax benefits - January 1		$	540		$	271		$	131		$	67		$	44	$	36	$	32
	Gross decreases - tax positions in prior periods			-230			-96			-85			-45			-37		-36		-31
	Settlements			-66			-4			―			―			―		―		―
		Total changes		-296			-100			-85			-45			-37		-36		-31
	Unrecognized tax benefits - September 30^(a)		$	244		$	171		$	46		$	22		$	7	$	―	$	1

	(a)	The Duke Energy Registrants do not anticipate a significant increase or decrease in unrecognized tax benefits in the next twelve months.

Schedule of Excise Taxes	'
			Three Months Ended September 30,							Nine Months Ended September 30,
	(in millions)				2013			2012				2013			2012
	Duke Energy			$	170		$	178			$	461		$	325
	Duke Energy Carolinas				46			47				124			125
	Progress Energy				89			95				230			241
	Duke Energy Progress				33			33				88			85
	Duke Energy Florida				56			62				142			156
	Duke Energy Ohio				26			26				81			79
	Duke Energy Indiana				9			9				26			25

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	9 Months Ended
Related Party Transactions (Tables)	Sep. 30, 2013
Duke Energy Carolinas [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Progress Energy [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Duke Energy Progress [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Duke Energy Florida [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Duke Energy Ohio [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Duke Energy Indiana [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Three Months Ended September 30,					Nine Months Ended September 30,
	(in millions)				2013	2012				2013	2012
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)			$	236	$	309		$	714	$	798
	Indemnification coverages^(b)				5		5			16		16
	Joint Dispatch Agreement (JDA) revenue^(c)				24		8			101		8
	JDA expense^(c)				39		37			71		37
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)			$	54	$	31		$	327	$	31
	Corporate governance and shared services provided to Duke Energy^(d)				24		30			74		30
	Indemnification coverages^(b)				9		7			26		7
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)			$	33	$	72		$	195	$	183
	Indemnification coverages^(b)				5		3			15		3
	JDA revenue^(c)				39		37			71		37
	JDA expense^(c)				24		8			101		8
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)			$	20	$	52		$	131	$	136
	Indemnification coverages^(b)				4		4			11		4
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)			$	89	$	103		$	261	$	279
	Indemnification coverages^(b)				3		4			11		11
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)			$	113	$	118		$	313	$	317
	Indemnification coverages^(b)				5		2			10		6

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(c)	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
	(d)	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Organization_and_Basis_of_Pres3

Organization and Basis of Presentation (Schedule of Unbilled Revenues with Restricted Receivables) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	$856	'	$856	'	$920
Income Amounts Attributable to Parent, Disclosures [Abstract]	'	'	'	'	'
Net income (loss) attributable to Duke Energy Corporation	1,004	594	1,977	1,333	'
Duke Energy Carolinas [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	288	'	288	'	315
Progress Energy [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	220	'	220	'	187
Income Amounts Attributable to Parent, Disclosures [Abstract]	'	'	'	'	'
Net income (loss) attributable to Duke Energy Corporation	341	155	477	368	'
Duke Energy Progress [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	120	'	120	'	112
Duke Energy Florida [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	100	'	100	'	74
Duke Energy Ohio [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	33	'	33	'	47
Duke Energy Ohio [Member] \| CRC [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	65	'	65	'	90
Duke Energy Indiana [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	3	'	3	'	3
Duke Energy Indiana [Member] \| CRC [Member]	'	'	'	'	'
Unbilled Receivables [Abstract]	'	'	'	'	'
Unbilled receivables, current	$126	'	$126	'	$132

Acquisitions_and_Sales_of_Othe2

Acquisitions and Sales of Other Assets (Narrative) (Details) (USD $)

3 Months Ended

9 Months Ended

6 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

9 Months Ended

0 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2012

Sep. 30, 2013

Jul. 02, 2012

Dec. 31, 2012

Jun. 30, 2012

Jan. 12, 2012

Dec. 31, 2012

Apr. 30, 2013

Oct. 04, 2013

Jan. 12, 2012

Sep. 30, 2012

Jan. 12, 2012

Sep. 30, 2013

Sep. 30, 2012

Purchase Price Allocation Adjustments [Member]

Sumitomo Corporation of America [Member]

Wabash Valley Power Association [Member]

Ibener [Member]

DukeNet [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Scenario Forecast [Member]

Significant Acquisitions and Disposals [Line Items]

Adjusted conversion ratio, after reverse stock split adjustment

87.08%

Fair value of outstanding earned stock compensation awards

$62

Total estimated purchase price

18,071

Costs to achieve the merger

293

322

Transfer of Vermillion Generating Station

Proceeds from sale of interest in jointly owned utility plant

Sale of ownership interest in Vermillion Generating Station

75.00%

Equity ownership interest rate

50.00%

37.50%

62.50%

Construction and 12-year amortizing term loan facility

330

Proceeds from issuance of other long-term debt

319

Cash collateral returned

192

Cash paid

415

Property, plant and equipment

23,141

-138

383

Intangibles

Deferred tax

Working capital

3,204

Goodwill

12,469

Proceeds from divestiture of interest in joint venture

210

Other long-term assets, excluding goodwill

$9,990

($4)

Acquisitions_and_Sales_of_Othe3

Acquisitions and Sales of Other Assets (Accounting Charges) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	$5	$146	$30	$146
FERC mitigation	'	'	0	117
Duke Energy Carolinas [Member]	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	0	48	7	48
FERC mitigation	'	'	0	46
Progress Energy [Member]	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	4	66	17	66
FERC mitigation	'	'	0	71
Duke Energy Progress [Member]	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	3	42	12	42
FERC mitigation	'	'	0	71
Duke Energy Florida [Member]	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	1	24	5	24
Duke Energy Ohio [Member]	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	0	15	2	15
Duke Energy Indiana [Member]	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Severance costs 1	$0	$13	$2	$13

Acquisitions_and_Sales_of_Othe4

Acquisitions and Sales of Other Assets (Purchase Price Calculation) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Jul. 02, 2012	Dec. 31, 2011
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Jul. 02, 2012	Dec. 31, 2011
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'
Progress Energy common shares outstanding	706,000,000	704,000,000	704,000,000	'	445,000,000
Exchange ratio	'	'	'	87.08%	'
Fair value of outstanding earned stock compensation awards	'	'	'	$62	'
Total estimated purchase price	$18,071	'	'	$18,071	'
Progress Energy [Member]	'	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'
Progress Energy common shares outstanding	100	100	'	'	'

Acquisitions_and_Sales_of_Othe5

Acquisitions and Sales of Other Assets (Purchase Price Allocation) (Details) (USD $)	Sep. 30, 2013	Jul. 02, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Jul. 02, 2012
Significant Acquisitions and Disposals [Line Items]	'	'
Current assets	$3,204	'
Property, plant and equipment	23,141	'
Goodwill	12,469	'
Other long-term assets, excluding goodwill	9,990	'
Total assets	48,804	'
Current liabilities, including current maturities of long-term debt	3,593	'
Long-term liabilities, preferred stock and noncontrolling interests	10,394	'
Long-term debt	16,746	'
Total liabilities and preferred stock	30,733	'
Total estimated purchase price	$18,071	$18,071

Acquisitions_and_Sales_of_Othe6

Acquisitions and Sales of Other Assets (Pro Forma Financial Information) (Details) (USD $)	3 Months Ended	9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2012	Sep. 30, 2012
Significant Acquisitions and Disposals [Line Items]	'	'
Revenues	$6,727	$18,309
Net Income Attributable to Duke Energy Corporation	$889	$1,888
Basic Earnings Per Share	$1.26	$2.68
Diluted Earnings Per Share	$1.26	$2.68

Acquisitions_and_Sales_of_Othe7

Acquisitions and Sales of Other Assets (Narrative - Change in PPA) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Purchase Price Allocation Adjustments [Member]
Significant Acquisitions and Disposals [Line Items]	'	'
Current assets	$3,204	'
Property, plant and equipment	23,141	-138
Goodwill	12,469	2
Other long-term assets, excluding goodwill	9,990	-4
Current liabilities, including current maturities of long-term debt	3,593	12
Long-term liabilities, preferred stock and noncontrolling interests	$10,394	($152)

Business_Segments_Narrative_De

Business Segments (Narrative) (Details)	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Jan. 12, 2012
Business Segments (Narrative) (Details)	International Energy Interest In National Methanol [Member]	Duke Energy Interest In Detm [Member]	DukeNet [Member]	Duke Energy Indiana [Member]
Segment Reporting Information [Line Items]	'	'	'	'
Equity ownership interest rate	25.00%	60.00%	50.00%	62.50%

Business_Segments_Business_Seg

Business Segments (Business Segment Data) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012		Dec. 31, 2012
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	$6,709		$6,722		$18,486		$13,929		'
Segment income	990	[1],[2],[3],[4]	590	[5],[6]	1,966	[1],[2],[3],[7],[8],[9]	1,328	[10],[11]	'
Add back Noncontrolling interest component	4		4		7		12		'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	14		4		11		5		'
Net Income (Loss)	1,008		598		1,984		1,345		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	114,590		'		114,590		'		113,856
Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	6,709	[1],[2],[3]	6,722		18,486	[1],[2],[3]	13,929		'
Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	0		0		0		0		'
U S Franchised Electric And Gas [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	5,786		5,842		15,766		11,207		'
Segment income	923	[1],[2],[3]	790	[5]	1,932	[1],[2],[3],[7],[8]	1,263	[10]	'
Segments Notes To Tables [Abstract]	'		'		'		'		'
After-tax deferral of voluntary severance program expense	'		'		'		60		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	99,269		'		99,269		'		'
U S Franchised Electric And Gas [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	5,768	[1],[2],[3]	5,830		15,731	[1],[2],[3]	11,178		'
U S Franchised Electric And Gas [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	18		12		35		29		'
Commercial Power [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	550		525		1,559		1,607		'
Segment income	27		12		26		71		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	6,852		'		6,852		'		'
Commercial Power [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	541		508		1,527		1,560		'
Commercial Power [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	9		17		32		47		'
International Energy [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	370		382		1,168		1,181		'
Segment income	116		103		300		350		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	5,669		'		5,669		'		'
International Energy [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	370		382		1,168		1,181		'
International Energy [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	'		0		0		0		'
Total Reportable Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	6,706		6,749		18,493		13,995		'
Segment income	1,066	[1],[2],[3]	905	[5]	2,258	[1],[2],[3],[7],[8]	1,684	[10]	'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	111,790		'		111,790		'		'
Total Reportable Segments [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	6,679	[1],[2],[3]	6,720		18,426	[1],[2],[3]	13,919		'
Total Reportable Segments [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	27		29		67		76		'
All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	54		20		125		51		'
Segment income	-76	[4]	-315	[6]	-292	[9]	-356	[11]	'
Segments Notes To Tables [Abstract]	'		'		'		'		'
After-tax costs to achieve the merger	54		293		139		306		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	2,658		'		2,658		'		'
All Other Segments [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	30		2		60		10		'
All Other Segments [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	24		18		65		41		'
Intersegment Eliminations [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	-51		-47		-132		-117		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	142		'		142		'		'
Intersegment Eliminations [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	-51		-47		-132		-117		'
Duke Energy Carolinas [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	1,919		1,939		5,239		5,056		'
Net Income (Loss)	342		258		767		735		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	31,552		'		31,552		'		30,642
Duke Energy Carolinas [Member] \| Rate Case Step One [Member] \| NCUC [Member]	'		'		'		'		'
Segments Notes To Tables [Abstract]	'		'		'		'		'
Approved rate increase amount by state commission	'		'		205		'		'
Duke Energy Carolinas [Member] \| All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Segment income	-26		-119		-69		-137		'
Progress Energy [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	2,766		2,788		7,233		7,178		'
Add back Noncontrolling interest component	1		2		2		5		'
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	14		3		10		10		'
Net Income (Loss)	342		157		479		373		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	37,430		'		37,430		'		37,405
Progress Energy [Member] \| All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Segment income	-72		-181		-205		-278		'
Duke Energy Progress [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	1,430		1,398		3,781		3,578		'
Net Income (Loss)	175		96		362		180		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	18,542		'		18,542		'		18,068
Duke Energy Progress [Member] \| Rate Case Step One [Member] \| NCUC [Member]	'		'		'		'		'
Segments Notes To Tables [Abstract]	'		'		'		'		'
Approved rate increase amount by state commission	'		'		147		'		'
Duke Energy Progress [Member] \| All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Segment income	-20		-109		-40		-119		'
Duke Energy Florida [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	1,332		1,388		3,442		3,594		'
Net Income (Loss)	197		100		250		311		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	14,845		'		14,845		'		15,180
Duke Energy Florida [Member] \| All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Segment income	-6		-23		-18		-30		'
Duke Energy Ohio [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	819		757		2,377		2,386		'
Segment income	59	[12]	14		96	[12]	133		'
Net Income (Loss)	59		14		96		133		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	10,657		'		10,657		'		10,560
Duke Energy Ohio [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	819	[12]	757		2,377	[12]	2,386		'
Duke Energy Ohio [Member] \| Electric Rate Case [Member] \| PUCO [Member]	'		'		'		'		'
Segments Notes To Tables [Abstract]	'		'		'		'		'
Approved rate increase amount by state commission	'		'		49		'		'
Duke Energy Ohio [Member] \| Franchised Electric & Gas [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	421		431		1,317		1,291		'
Segment income	42	[12]	49		122	[12]	113		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	6,631		'		6,631		'		'
Duke Energy Ohio [Member] \| Franchised Electric & Gas [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	421	[12]	431		1,317	[12]	1,291		'
Duke Energy Ohio [Member] \| DEO Commercial Power [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	404		341		1,085		1,137		'
Segment income	30		-17		-3		44		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	4,088		'		4,088		'		'
Duke Energy Ohio [Member] \| DEO Commercial Power [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	398		326		1,060		1,095		'
Duke Energy Ohio [Member] \| DEO Commercial Power [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	6		15		25		42		'
Duke Energy Ohio [Member] \| Total Reportable Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	825		772		2,402		2,428		'
Segment income	72	[12]	32		119	[12]	157		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	10,719		'		10,719		'		'
Duke Energy Ohio [Member] \| Total Reportable Segments [Member] \| Unaffiliated [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	819	[12]	757		2,377	[12]	2,386		'
Duke Energy Ohio [Member] \| Total Reportable Segments [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	6		15		25		42		'
Duke Energy Ohio [Member] \| All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Segment income	-13		-18		-23		-24		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	103		'		103		'		'
Duke Energy Ohio [Member] \| Intersegment Eliminations [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	-6		-15		-25		-42		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	-165		'		-165		'		'
Duke Energy Ohio [Member] \| Intersegment Eliminations [Member] \| Intersegment [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	-6		-15		-25		-42		'
Duke Energy Indiana [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Operating revenues	755		718		2,179		2,091		'
Net Income (Loss)	104		-19		276		-109		'
Segment Reporting Information Assets [Abstract]	'		'		'		'		'
Segment assets	10,336		'		10,336		'		10,008
Duke Energy Indiana [Member] \| All Other Segments [Member]	'		'		'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'		'		'
Segment income	($5)		($14)		($13)		($19)		'

[1]	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
[2]	In June 2013, Duke Energy Progress implemented revised customer rates approved by the NCUC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
[3]	In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. This increase impacts USFE&G. See Note 4 for additional information about the revised customer rates.
[4]	Other includes after-tax costs to achieve the merger with Progress Energy of $54 million. See Note 2 for additional information about the merger.
[5]	USFE&G recorded an impairment related to the Edwardsport Integrated Gasification Combined Cycle (IGCC) project. See Note 4 for additional information on the Edwardsport impairment.
[6]	Other includes after-tax costs to achieve the merger with Progress Energy of $293 million. See Note 2 for additional information about the merger.
[7]	USFE&G recorded an impairment charge related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information about the Crystal River Unit 3 impairment.
[8]	USFE&G recorded an impairment charge related to Duke Energy Progress' Shearon Harris Nuclear Station (Harris) site. USFE&G also recorded an impairment charge related to Duke Energy Florida's proposed Levy Nuclear Station (Levy). See Note 4 for additional information about the Harris site and Levy site impairments.
[9]	Other includes after-tax costs to achieve the merger with Progress Energy of $139 million. See Note 2 for additional information about the merger.
[10]	USFE&G recorded an impairment charge related to Duke Energy Indiana's IGCC project. USFE&G also recorded the reversal of expenses of $60 million related to a prior year Voluntary Opportunity Plan in accordance with Duke Energy Carolinas' 2011 rate case. See Note 4 for additional information about the impairment charges.
[11]	Other includes after-tax costs to achieve the merger with Progress Energy of $306 million. See Note 2 for additional information about the merger.
[12]	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts FE&G. See Note 4 for additional information about the revised customer rates.

Regulatory_Matters_Narrative_D

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

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

36 Months Ended

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Duke Energy Carolinas [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Retired Generation Facilities [Member]

Rate Case [Member]

Rate Case Step One [Member]

Rate Case Step Two [Member]

V.C. Summer Nuclear Station [Member]

William State Lee III Nuclear Station [Member]

Retired Generation Facilities [Member]

Rate Case [Member]

Rate Case Step One [Member]

Rate Case Step Two [Member]

L V Sutton Plant [Member]

Shearon Harris Nuclear Station [Member]

2012 FPSC Settlement Agreement [Member]

2013 FPSC Settlement Agreement [Member]

Crystal River Unit 3 [Member]

Levy Nuclear Station [Member]

New Generation Needs [Member]

Electric Rate Case [Member]

Natural Gas Rate Case [Member]

Capacity Rider Filing [Member]

RTO Realignment [Member]

Retired Generation Facilities [Member]

Edwardsport IGCC Plant [Member]

NCUC [Member]

PSCSC [Member]

NCUC [Member]

PSCSC [Member]

NCUC [Member]

PSCSC [Member]

Minimum [Member]

Maximum [Member]

NCUC [Member]

Minimum [Member]

Maximum [Member]

Amount Subject To Cost Cap [Member]

Uprate And Dry Cask Storage Projects [Member]

Minimum [Member]

Maximum [Member]

2012 FPSC Settlement Agreement [Member]

2013 FPSC Settlement Agreement [Member]

NEIL Settlement [Member]

2013 FPSC Settlement Agreement [Member]

PUCO [Member]

Edwardsport Event April 16, 2010 [Member]

Edwardsport Event June 27, 2011 [Member]

Edwardsport Event October 19, 2011 [Member]

Edwardsport Event October 30, 2012 [Member]

Edwardsport Event November 20, 2007 [Member]

Edwardsport Event January 2009

Edwardsport Event December 27, 2012

Removal Costs Reduction Year One [Member]

Removal Costs Reduction Year Two [Member]

Removal Costs Reduction [Member]

Public Utilities, General Disclosures [Line Items]

Combined cycle capacity, MW

1,150

Additional generation capacity, MW

1,800

Estimated AFUDC on capital project

$160,000,000

$125,000,000

Estimated capital cost of new utility plant, including AFUDC

570,000,000

Percentage of completion of construction

94.00%

Net property, plant and equipment

69,284,000,000

68,558,000,000

23,185,000,000

22,826,000,000

370,000,000

13,442,000,000

13,062,000,000

9,514,000,000

9,360,000,000

117,000,000

8,191,000,000

8,126,000,000

8,471,000,000

8,320,000,000

VC summer ownership percentage

5.00%

10.00%

Approved rate increase amount by state commission

205,000,000

80,000,000

30,000,000

38,000,000

147,000,000

31,000,000

150,000,000

49,000,000

Requested rate increase amount to state commission

63,000,000

Rate increase begin date

'9/25/2013

'9/18/2013

'6/1/2013

'5/1/2013

Approved rate increase percentage by state commission

4.50%

5.50%

0.60%

2.60%

4.50%

1.00%

2.90%

Approved return on equity percentage amount by state commission

10.20%

9.50%

11.50%

7.35%

10.50%

9.84%

Approved equity capital structure, percentage

53.00%

Required shareholder contribution to low income customers or agencies.

10,000,000

4,000,000

20,000,000

Impairment charges

2,000,000

266,000,000

388,000,000

668,000,000

31,000,000

55,000,000

22,000,000

55,000,000

22,000,000

1,000,000

346,000,000

295,000,000

65,000,000

180,000,000

580,000,000

600,000,000

897,000,000

Edwardsport IGCC original estimated and approved capital cost, including AFUDC

1,985,000,000

Edwardsport IGCC revised estimated capital cost, including AFUDC

2,880,000,000

2,350,000,000

Cost Cap for customers

1,466,000,000

2,595,000,000

Edwardsport IGCC revised estimated capital costs, excluding AFUDC

2,820,000,000

2,980,000,000

3,150,000,000

EPA compliance capital costs

395,000,000

Capacity rider revenues requested

729,000,000

MVP project costs approved by MISO

5,500,000,000

Future revenue requirement discount rate

8.20%

MVP projects future revenue requirements obligation

514,000,000

Recovery costs not sought

121,000,000

Repair costs, range of possible costs

900,000,000

1,300,000,000

Net unrecovered investment

265,000,000

Public utilities, cost of removal reserve, reduction taken subject to regulatory order

22,000,000

60,000,000

95,000,000

118,000,000

Public utilities, cost of removal reserve, amount subject to regulatory order

19,000,000

Refund to customers recorded as reduction to revenue

288,000,000

100,000,000

Independent review repair costs

1,490,000,000

3,430,000,000

Decommissioning cost study estimate

989,000,000

Total insurance proceeds received to date

835,000,000

Current year insurance proceeds received to date

530,000,000

Future customer credit

10,000,000

Acceleration of cash recovery through fuel clause

135,000,000

Decommissioning trust funding

8,000,000

Regulatory assets, noncurrent

10,220,000,000

11,004,000,000

1,794,000,000

1,727,000,000

71,000,000

1,558,000,000

1,845,000,000

187,000,000

47,000,000

3,007,000,000

3,321,000,000

1,186,000,000,000

324,000,000

118,000,000

556,000,000

579,000,000

70,000,000

790,000,000

810,000,000

57,000,000

Regulatory liability, noncurrent

5,904,000,000

5,584,000,000

2,484,000,000

2,102,000,000

30,000,000

45,000,000

1,743,000,000

1,538,000,000

20,000,000

640,000,000

787,000,000

490,000,000

257,000,000

254,000,000

766,000,000

741,000,000

Other current assets

$30,000,000

Regulatory_Matters_Refunds_Det

Regulatory Matters (Refunds) (Details) (Duke Energy Florida [Member], USD $)	9 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Florida Public Service Commission Settlement Agreement 2012 [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
Customer refunds to date	$97	'	'	'
Total Customer Refunds To Be Paid	288	'	'	'
Florida Public Service Commission Settlement Agreement 2012 [Member] \| Scenario Forecast [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
2013	32	'	'	'
2014	'	'	'	139
2015	'	'	10	'
2016	'	10	'	'
Retirement Decision Credits [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
2015	'	'	40	'
2016	'	60	'	'
Total Customer Refunds To Be Paid	100	'	'	'
Neil Settlement [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
Customer refunds to date	245	'	'	'
Total Customer Refunds To Be Paid	490	'	'	'
Neil Settlement [Member] \| Scenario Forecast [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
2013	81	'	'	'
2014	'	'	'	164
Total Customer Refunds [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
Customer refunds to date	342	'	'	'
Total Customer Refunds To Be Paid	878	'	'	'
Total Customer Refunds [Member] \| Scenario Forecast [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
2013	113	'	'	'
2014	'	'	'	303
2015	'	'	50	'
2016	'	70	'	'
Accelerated Regulatory Asset Recovery [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
Total Customer Refunds To Be Paid	-135	'	'	'
Accelerated Regulatory Asset Recovery [Member] \| Scenario Forecast [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
2014	'	'	'	-38
2015	'	'	-38	'
2016	'	-59	'	'
Net Customer Refunds [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
Customer refunds to date	342	'	'	'
Total Customer Refunds To Be Paid	743	'	'	'
Net Customer Refunds [Member] \| Scenario Forecast [Member]	'	'	'	'
Regulatory Assets Liabilities [Line Items]	'	'	'	'
2013	113	'	'	'
2014	'	'	'	265
2015	'	'	12	'
2016	'	$11	'	'

Regulatory_Matters_Schedule_of

Regulatory Matters (Schedule of Net Carrying Value Of Facilities As Well As the Remaining Non-current Regulatory Assets) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
	MW
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	3,244
Remaining net book value of potential plants to be retired	$319	[1]
Duke Energy Carolinas [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	200	[2]
Remaining net book value of potential plants to be retired	14	[1],[2]
Progress Energy [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	1,448
Remaining net book value of potential plants to be retired	171	[1]
Duke Energy Progress [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	575	[3],[4]
Remaining net book value of potential plants to be retired	59	[1],[3],[4]
Duke Energy Florida [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	873	[5]
Remaining net book value of potential plants to be retired	112	[1],[5]
Duke Energy Ohio [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	928	[6]
Remaining net book value of potential plants to be retired	10	[1],[6]
Duke Energy Indiana [Member]	'
Public Utilities, General Disclosures [Line Items]	'
Megawatt of potential plants to be retired	668	[7]
Remaining net book value of potential plants to be retired	$124	[1],[7]

[1]	Included in Property, plant and equipment, net as of September 30, 2013, on the Condensed Consolidated Balance Sheets, unless otherwise noted.
[2]	Includes Lee Units 1 and 2. Excludes 170 MW Lee Unit 3 that is expected to be converted to gas in 2014. Duke Energy Carolinas expects to retire or convert these units by December 2020 in conjunction with a settlement agreement associated with the Cliffside Unit 6 air permit.
[3]	Includes Sutton Station, which is expected to be retired by the end of 2013.
[4]	Remaining net book value of Duke Energy Progress' Sutton Station is included in Generation facilities to be retired, net, on the Condensed Consolidated Balance Sheets at September 30, 2013.
[5]	Includes Crystal River Units 1 and 2.
[6]	Includes Beckjord Station Units 2 through 6 and Miami Fort Unit 6. Beckjord units have no remaining book value. Beckjord units 2 and 3 were retired effective October 1, 2013.
[7]	Includes Wabash River Units 2 through 6. Wabash River Unit 6 is being evaluated for potential conversion to gas. Duke Energy Indiana committed to retire or convert these units by June 2018 in conjunction with a settlement agreement associated with the Edwardsport air permit.

Regulatory_Matters_Schedule_of1

Regulatory Matters (Schedule of MISO Exit fees)(Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	$135
Cash reductions	114
Restructuring reserve, period expense	-41	[1]
Balance at September 30, 2013	62
Duke Energy Ohio [Member] \| RTO Realignment [Member]	'
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	97
Cash reductions	-3
Restructuring reserve, accrual adjustment	3
Balance at September 30, 2013	$97	[2]

[1]	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.
[2]	As of September 30, 2013, $70 million is recorded as a Regulatory asset on Duke Energy Ohio's Condensed Consolidated Balance Sheets.

Commitments_and_Contingencies_1

Commitments and Contingencies (Narrative) (Details) (USD $)	9 Months Ended		12 Months Ended
Commitments and Contingencies (Narrative) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2009	Dec. 31, 2012
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	$75,000,000		'	'
Probable insurance recoveries	649,000,000	[1],[2]	'	781,000,000	[1],[2]
Minimum [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Estimated cost of complying with recently issued and proposed EPA regulations	5,000,000,000		'	'
Maximum [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Estimated cost of complying with recently issued and proposed EPA regulations	6,000,000,000		'	'
Alaskan Global Warming Lawsuit [Member] \| Minimum [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Damages Sought, Value	95,000,000		'	'
Alaskan Global Warming Lawsuit [Member] \| Maximum [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Damages Sought, Value	400,000,000		'	'
Brazil Expansion Lawsuit [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Obligation to expand installed generation capacity, percent	15.00%		'	'
Crescent Litigation [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Damages Sought, Value	1,200,000,000		'	'
Settlement offer to plaintiffs, partial	50,000,000		'	'
Crescent Litigation [Member] \| Interest Expense [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Damages Sought, Value	252,000,000		'	'
Crescent Litigation [Member] \| Bank Fees Member [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Damages Sought, Value	15,000,000		'	'
Duke Energy Carolinas [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	29,000,000		'	'
Probable insurance recoveries	649,000,000	[1],[2]	'	781,000,000	[1],[2]
Duke Energy Carolinas [Member] \| New Source Review Provisions Of Clean Air Act [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
New Source Review maximum civil penalties per day for each violation	37,500		'	'
Duke Energy Carolinas [Member] \| Asbestos Issue [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Liability for Asbestos and Environmental Claims, Gross	633,000,000		'	751,000,000
Reinsurance Retention Policy, Amount Retained	476,000,000		'	'
Reinsurance Retention Policy, Excess Retention, Amount Reinsured	897,000,000		'	'
Duke Energy Carolinas [Member] \| Asbestos Issue [Member] \| Malignant Asbestos Claim [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Pending Claims, Number	35		'	'
Liability for Asbestos and Environmental Claims, Gross	11,000,000		'	'
Duke Energy Carolinas [Member] \| Asbestos Issue [Member] \| Non Malignant Asbestos Claim [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Pending Claims, Number	157		'	'
Liability for Asbestos and Environmental Claims, Gross	30,000,000		'	'
Progress Energy [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	6,000,000		'	'
Progress Energy [Member] \| Synthetic Fuels [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Damages Paid, Value	'		154,000,000	'
Damages awarded to plaintiff	90,000,000		'	'
Gain recognized in period	'		'	63,000,000
Duke Energy Progress [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	3,000,000		'	'
Duke Energy Progress [Member] \| Spent Nuclear Fuels [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Gain Contingency, Unrecorded Amount	84,000,000		'	'
Duke Energy Florida [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	3,000,000		'	'
Duke Energy Florida [Member] \| Spent Nuclear Fuels [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Gain Contingency, Unrecorded Amount	21,000,000		'	'
Duke Energy Ohio [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	35,000,000		'	'
Duke Energy Indiana [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss Contingency, Range of Possible Loss, Portion Not Acccrued	5,000,000		'	'
Duke Energy Indiana [Member] \| Edwardsport Igcc Plant [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Gain Contingency, Unrecorded Amount	$560,000,000		'	'

[1]	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
[2]	Relates to recoveries associated with asbestos-related injuries and damages claims.

Committments_and_Contingencies

Committments and Contingencies (Schedule of Reserves and Insurance Recoveries) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	$782	[1],[2]	$846	[1],[2]
Probable insurance recoveries	649	[3],[4]	781	[3],[4]
Duke Energy Carolinas [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	633	[1],[2]	751	[1],[2]
Probable insurance recoveries	649	[3],[4]	781	[3],[4]
Progress Energy [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	74	[1]	79	[1]
Duke Energy Progress [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	10	[1]	12	[1]
Duke Energy Florida [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	43	[1],[5]	47	[1],[5]
Duke Energy Indiana [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	$8	[1]	$8	[1]

[1]	Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
[2]	Includes reserves for asbestos-related injuries and damages claims.
[3]	Insurance recoveries are classified on the Condensed Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
[4]	Relates to recoveries associated with asbestos-related injuries and damages claims.
[5]	Includes workers' compensation claims.

Commitments_and_Contingencies_2

Commitments and Contingencies (Schedule of Environmental Loss Contingencies)(Details) (USD $)

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Minimum [Member]

Maximum [Member]

Duke Energy Carolinas [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Accrual for Environmental Loss Contingencies [Roll Forward]

Beginning balance

$75

$61

$12

$15

$28

$33

$23

$14

$11

$19

$12

Provision/adjustments

-1

Cash reductions

-17

-19

-8

-15

-2

-6

-7

-2

-4

-5

Ending balance

Estimated cost of complying with EPA Mercury and Air Toxics Standards

$650

$800

$65

$85

$40

$85

$540

$600

$30

$10

$20

Debt_and_Credit_Facilities_Sum

Debt and Credit Facilities (Summary of Debt Issuances) (Details) (USD $)

Sep. 30, 2013

Oct. 31, 2013

Sep. 30, 2013

Oct. 31, 2013

In Millions, unless otherwise specified

January 2013 5.125% Junior Subordinated Debentures Maturing January 2073 [Member]

February 2013 4.740% Term Loans Maturing June 2037 [Member]

February 2013 2.043% Term Loans Maturing December 2030 [Member]

March 2013 4.100% First Mortgage Bonds Maturing March 2043 [Member]

April 2013 5.456% Non Recourse Secured Credit Facility Maturing April 2026 [Member]

June 2013 2.100% Senior Notes Maturing June 2018 [Member]

June 2013 4.00% Senior Notes Maturing June 2041 [Member]

July 2013 4.900% First Mortgage Bonds Maturing July 2043 [Member]

July 2013 0.619% First Mortgage Bonds Maturing July 2016 [Member]

August 2013 11.000% Non Convertible Debentures Maturing August 2018 [Member]

September 2013 3.800% First Mortgage Bonds Maturing September 2023 [Member]

September 2013 0.400% First Mortgage Bonds Maturing March 2015 [Member]

October 2013 3.950% Senior Notes Maturing October 2023 [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Parent Company [Member]

Unsecured Debt [Member]

Secured Debt [Member]

First Mortgage Bonds [Member]

Bridge Loan [Member]

Secured Debt [Member]

Unsecured Debt [Member]

First Mortgage Bonds [Member]

Unsecured Debt [Member]

First Mortgage Bonds [Member]

Unsecured Debt [Member]

January 2013 5.125% Junior Subordinated Debentures Maturing January 2073 [Member]

March 2013 4.100% First Mortgage Bonds Maturing March 2043 [Member]

June 2013 4.00% Senior Notes Maturing June 2041 [Member]

September 2013 3.800% First Mortgage Bonds Maturing September 2023 [Member]

September 2013 0.400% First Mortgage Bonds Maturing March 2015 [Member]

July 2013 4.900% First Mortgage Bonds Maturing July 2043 [Member]

July 2013 0.619% First Mortgage Bonds Maturing July 2016 [Member]

January 2013 5.125% Junior Subordinated Debentures Maturing January 2073 [Member]

June 2013 2.100% Senior Notes Maturing June 2018 [Member]

October 2013 3.950% Senior Notes Maturing October 2023 [Member]

Subsequent Event [Member]

Corporate Debt Securities [Member]

First Mortgage Bonds [Member]

Unsecured Debt [Member]

Subsequent Event [Member]

Debt Instrument [Line Items]

Debt issuance date

31-Jan-13

28-Feb-13

31-Mar-13

30-Apr-13

30-Jun-13

31-Jul-13

31-Aug-13

30-Sep-13

31-Oct-13

31-Mar-13

30-Jun-13

30-Sep-13

31-Jul-13

31-Jan-13

30-Jun-13

31-Oct-13

Debt maturity date

31-Jan-73

30-Jun-37

31-Dec-30

31-Mar-43

30-Apr-26

30-Jun-18

30-Jun-41

31-Jul-43

31-Jul-16

30-Sep-23

31-Mar-15

31-Oct-23

31-Mar-43

30-Jun-41

30-Sep-23

31-Mar-15

31-Jul-43

31-Jul-16

31-Jan-73

30-Jun-18

31-Oct-23

Debt maturity date, start

31-Aug-18

Debt maturity date, end

31-Aug-23

Debt issuances

$3,771

$500

[1]

$220

[2]

$203

[2],[3]

$500

[4]

$230

[5]

$500

[6]

$48

[7]

$350

[8]

$150

[8],[9]

$220

[10],[11]

$300

[12]

$150

[12],[13]

$400

[14]

$548

$500

[4]

$48

[7]

$450

$300

[12]

$150

[12],[13]

$500

$350

[8]

$150

[8],[9]

$1,400

$500

[1]

$500

[6]

$400

[14]

Interest rate

5.13%

4.74%

2.04%

4.10%

5.46%

2.10%

4.00%

4.90%

0.62%

11.00%

3.80%

0.40%

3.95%

7.10%

4.10%

4.00%

3.80%

0.40%

4.90%

0.62%

5.13%

2.10%

3.95%

Debt instrument, call date, earliest

31-Jan-18

30-Jun-23

31-Jan-18

Payments for the redemption of debt

190

250

400

200

250

300

250

400

250

Percentage of debt hedged by interest rate derivatives

95.00%

75.00%

Incremental debt proceeds

$40

Fixed credit spread

0.35%

0.14%

0.35%

[1]

Callable after January 2018 at par. Proceeds from the issuance were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS). The securities were redeemed at par plus accrued and unpaid distributions, payable upon presentation on the redemption date. The remaining net proceeds were used to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 11 for additional information about the QUIPS.

[2]

Represents the conversion of construction loans related to a renewable energy project issued in December 2012 to term loans. No cash proceeds were received in conjunction with the conversion. The term loans have varying maturity dates. The maturity date presented represents the latest date for all components of the respective loans.

[3]

The debt is floating rate. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 95 percent of the loans.

[4]

Proceeds from the issuance were used to repay notes payable to affiliated companies as well as for general corporate purposes.

[5]

Represents primarily the conversion of a $190 million bridge loan issued in conjunction with the acquisition of Ibener in December 2012. Duke Energy received incremental proceeds of $40 million upon conversion of the bridge loan. The debt is floating rate and is denominated in U.S. dollars. Duke Energy has entered into a pay fixed-receive floating interest rate swap for 75 percent of the loan.

[6]

Proceeds from the issuance were used to repay $250 million of current maturities. The remaining net proceeds were used for general corporate purposes, including the repayment of outstanding commercial paper.

[7]

Callable after June 2023 at par. Proceeds from the issuance were used to redeem $48 million of First Mortgage Bonds with a higher interest rate.

[8]

Proceeds from the issuances were used to repay $400 million of current maturities.

[9]

The debt is floating rate based on 3-month London Interbank Offered Rate (LIBOR) and a fixed spread of 35 basis points.

[10]

Proceeds from the issuance were used to repay $200 million of current maturities. The maturity date included above applies to half of the instrument. The remaining half matures in August 2018.

[11]

The debt is floating rate based on a consumer price index and an overnight funds rate in Brazil. The debt is denominated in Brazilian Real.

[12]

Proceeds from the issuances were used for general corporate purposes including the repayment of short-term notes payable, a portion of which was incurred to fund the retirement of $250 million of first mortgage bonds that matured in the first half of 2013.

[13]

The debt is floating rate based on 3-month LIBOR plus a fixed spread of 14 basis points.

[14]

Proceeds from the issuance were used to repay commercial paper as well as for general corporate purposes.

Debt_and_Credit_Facilities_Ann

Debt and Credit Facilities (Annual Maturities) (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

In Millions, unless otherwise specified

Other Debt Obligations [Member]

Duke Energy Carolinas [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Parent Company [Member]

PGN Parent [Member]

5.750% Debt Maturing November 2013

6.300% Debt Maturing February 2014

3.950% Debt Maturing September 2014

6.050% Debt Maturing March 2014

First Mortgage Bonds [Member]

Unsecured Debt [Member]

Current Maturities Of Long Term Debt [Abstract]

Current maturities of long-term debt

$2,307

$3,110

$357

$447

$406

$400

$317

$843

$407

$11

$435

$261

$405

$750

$500

$300

Interest rate

5.75%

6.30%

3.95%

6.05%

Maturity date

30-Nov-13

28-Feb-14

30-Sep-14

31-Mar-14

Debt_and_Credit_Facilities_Sch

Debt and Credit Facilities (Schedule of Line of Credit Facilities) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Line of Credit Facility [Line Items]	'
Line of credit facility, affiliated borrower	'The Duke Energy Registrants each have borrowing capacity under the master credit facility up to specified sublimits for each borrower. Duke Energy has the unilateral ability at any time to increase or decrease the borrowing sublimits of each borrower, subject to a maximum sublimit for each borrower.
Maximum [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	6,000
Minimum [Member]	'
Line of Credit Facility [Line Items]	'
Line of credit facility, expiration date	1-Nov-17
Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	6,000	[1]
Available capacity	4,717
Notes payable and commercial paper	-979	[2]
Outstanding letters of credit	-64
Tax exempt bonds	-240
Duke Energy Carolinas [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	1,250	[1]
Available capacity	871
Notes payable and commercial paper	-300	[2]
Outstanding letters of credit	-4
Tax exempt bonds	-75
Duke Energy Progress [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	750	[1]
Available capacity	504
Notes payable and commercial paper	-244
Outstanding letters of credit	-2
Duke Energy Florida [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	750	[1]
Available capacity	749
Notes payable and commercial paper	0
Outstanding letters of credit	-1
Duke Energy Ohio [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	750	[1]
Available capacity	637
Notes payable and commercial paper	-29
Tax exempt bonds	-84
Duke Energy Indiana [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	750	[1]
Available capacity	519
Notes payable and commercial paper	-150	[2]
Tax exempt bonds	-81
Parent Company [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Facility size	1,750	[1]
Available capacity	1,437
Notes payable and commercial paper	-256
Outstanding letters of credit	-57
Parent Company [Member] \| Proceeds Loaned To Subsidiary Registrants [Member] \| Revolving Credit Facility [Member]	'
Line of Credit Facility [Line Items]	'
Notes payable and commercial paper	-450

[1]	Represents the sublimit of each borrower at September 30, 2013.
[2]	Duke Energy issued $450 million of commercial paper and loaned the proceeds through the money pool to Duke Energy Carolinas and Duke Energy Indiana. The balances are classified as long-term borrowings within Long-term Debt in Duke Energy Carolinabs and Duke Energy Indianabs Condensed Consolidated Balance Sheets.

Goodwill_Goodwill_By_Reportabl

Goodwill (Goodwill By Reportable Operating Segment) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Goodwill [Line Items]	'		'
Goodwill	$17,216		$17,236
Acquisitions	-1	[1]	'
Accumulated impairment charges	-871		-871
Foreign exchange and other changes	-19		'
Goodwill as adjusted for accumulated impairment charges	16,345		16,365
USFE&G [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill	15,950		15,950
Acquisitions	2	[1]	'
Foreign exchange and other changes	-2		'
Goodwill as adjusted for accumulated impairment charges	15,950		15,950
Commercial Power [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill	935		933
Acquisitions	2	[1]	'
Accumulated impairment charges	-871		-871
Goodwill as adjusted for accumulated impairment charges	64		62
International [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill	331		353
Acquisitions	-5	[1]	'
Foreign exchange and other changes	-17		'
Goodwill as adjusted for accumulated impairment charges	331		353
Progress Energy [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill as adjusted for accumulated impairment charges	3,655		3,655
Duke Energy Ohio [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill	2,324		2,325
Accumulated impairment charges	-1,404		-1,404
Foreign exchange and other changes	-1		'
Goodwill as adjusted for accumulated impairment charges	920		921
Duke Energy Ohio [Member] \| Franchised Electric & Gas [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill	1,136		1,137
Accumulated impairment charges	-216		-216
Foreign exchange and other changes	-1		'
Goodwill as adjusted for accumulated impairment charges	920		921
Duke Energy Ohio [Member] \| DEO Commercial Power [Member]	'		'
Goodwill [Line Items]	'		'
Goodwill	1,188		1,188
Accumulated impairment charges	-1,188		-1,188
Goodwill as adjusted for accumulated impairment charges	$0		$0

[1]	Amounts represent purchase price adjustments related to the Progress Energy merger at USFE&G, a minor renewables acquisition at Commercial Power and the Chilean hydro acquisition at International Energy. See Note 2 for further information on purchase price adjustments related to the Progress Energy Merger.

Risk_Management_Derivative_Ins2

Risk Management, Derivative Instruments and Hedging Activities (Narrative) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Derivative [Line Items]	'	'
Pretax deferred losses related to effective cash flow hedges	$65	$136
Amount expected to be recognized in earnings during the next 12 months	1	'
Undesignated commodity contracts latest expiration year	'2017	'
Undesignated commodity contracts latest expiration year for terminated operations	'2021	'
Duke Energy Carolinas [Member]	'	'
Derivative [Line Items]	'	'
Pretax deferred losses related to effective cash flow hedges	22	'
Progress Energy [Member]	'	'
Derivative [Line Items]	'	'
Pretax deferred losses related to effective cash flow hedges	60	71
Amount expected to be recognized in earnings during the next 12 months	5	'
Duke Energy Progress [Member]	'	'
Derivative [Line Items]	'	'
Pretax deferred losses related to effective cash flow hedges	'	1
Duke Energy Florida [Member]	'	'
Derivative [Line Items]	'	'
Pretax deferred losses related to effective cash flow hedges	'	$1

Risk_Management_Derivative_Ins3

Risk Management, Derivative Instruments and Hedging Activities (Notional Amounts of Derivative Instruments) (Details) (USD $)	9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
	GWh		GWh
	dth		dth
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	$1,224		$1,587
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Electricity-energy (Gigawatt-hours)	63,264		52,104
Natural gas (millions of decatherms)	536,000,000		528,000,000
Nondesignated [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	34		290
Cash Flow Hedging [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	1,190	[1]	1,047	[1]
Non-Recourse Debt	602		620
Fair Value Hedging [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		250
Duke Energy Carolinas [Member]	'		'
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Electricity-energy (Gigawatt-hours)	1,305		2,028
Progress Energy [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		50
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Electricity-energy (Gigawatt-hours)	925		1,850
Natural gas (millions of decatherms)	336,000,000		348,000,000
Progress Energy [Member] \| Nondesignated [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		50
Duke Energy Progress [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		50
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Electricity-energy (Gigawatt-hours)	925		1,850
Natural gas (millions of decatherms)	129,000,000		118,000,000
Duke Energy Progress [Member] \| Nondesignated [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		50
Duke Energy Florida [Member]	'		'
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Natural gas (millions of decatherms)	207,000,000		230,000,000
Duke Energy Ohio [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	27		277
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Electricity-energy (Gigawatt-hours)	59,662	[2]	51,215	[2]
Natural gas (millions of decatherms)	200,000,000		180,000,000
Duke Energy Ohio [Member] \| Nondesignated [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	27		27
Duke Energy Ohio [Member] \| Fair Value Hedging [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		250
Duke Energy Indiana [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		200
Underlying Notional Amounts For Derivative Instruments Accounted For At Fair Value [Abstract]	'		'
Electricity-energy (Gigawatt-hours)	702		97
Duke Energy Indiana [Member] \| Nondesignated [Member]	'		'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk [Abstract]	'		'
Derivative, Notional Amount	'		$200

[1]	Duke Energy includes amounts related to non-recourse variable rate long-term debt of VIEs of $602 million and $620 million at September 30, 2013, and at December 31, 2012, respectively.
[2]	Amounts at Duke Energy Ohio include intercompany positions that eliminate at Duke Energy.

Risk_Management_Derivative_Ins4

Risk Management, Derivative Instruments and Hedging Activities (Location and Fair Value Amounts of Derivatives Reflected in the Condensed Consolidated Balance Sheets) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	$374	$264
Location and fair value amounts of derivatives (Liability)	720	917
Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	159	127
Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	175	96
Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	338	402
Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	265	295
Designated As Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	21	9
Location and fair value amounts of derivatives (Liability)	67	119
Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	2
Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	21	7
Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	52	81
Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	14	35
Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	1	2
Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	1
Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	353	255
Location and fair value amounts of derivatives (Liability)	653	798
Nondesignated [Member] \| Interest Rate Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	1	76
Nondesignated [Member] \| Interest Rate Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	4	8
Nondesignated [Member] \| Commodity Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	46	41
Location and fair value amounts of derivatives (Liability)	1	2
Nondesignated [Member] \| Commodity Contracts [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	167	106
Location and fair value amounts of derivatives (Liability)	104	50
Nondesignated [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	136	106
Location and fair value amounts of derivatives (Liability)	372	407
Nondesignated [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	4	2
Location and fair value amounts of derivatives (Liability)	171	255
Duke Energy Carolinas [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	4	12
Duke Energy Carolinas [Member] \| Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	4	12
Duke Energy Carolinas [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	3	6
Duke Energy Carolinas [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	1	6
Progress Energy [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	3	11
Location and fair value amounts of derivatives (Liability)	285	440
Progress Energy [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	3
Progress Energy [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	2	8
Progress Energy [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	159	244
Progress Energy [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	122	192
Progress Energy [Member] \| Designated As Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	1	3
Progress Energy [Member] \| Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	2
Progress Energy [Member] \| Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	1	1
Progress Energy [Member] \| Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	3	11
Location and fair value amounts of derivatives (Liability)	284	437
Progress Energy [Member] \| Nondesignated [Member] \| Interest Rate Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	11
Progress Energy [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	3
Progress Energy [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	8
Progress Energy [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	'
Location and fair value amounts of derivatives (Liability)	159	231
Progress Energy [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	2	'
Location and fair value amounts of derivatives (Liability)	125	195
Duke Energy Progress [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	2
Location and fair value amounts of derivatives (Liability)	108	166
Duke Energy Progress [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	1
Duke Energy Progress [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	1
Duke Energy Progress [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	65	97
Duke Energy Progress [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	43	69
Duke Energy Progress [Member] \| Designated As Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	2
Duke Energy Progress [Member] \| Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	1
Duke Energy Progress [Member] \| Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	1
Duke Energy Progress [Member] \| Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	2
Location and fair value amounts of derivatives (Liability)	108	164
Duke Energy Progress [Member] \| Nondesignated [Member] \| Interest Rate Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	11
Duke Energy Progress [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	1
Duke Energy Progress [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	1
Duke Energy Progress [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	65	85
Duke Energy Progress [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	'
Location and fair value amounts of derivatives (Liability)	43	68
Duke Energy Florida [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	2	9
Location and fair value amounts of derivatives (Liability)	173	270
Duke Energy Florida [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	2
Duke Energy Florida [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	7
Duke Energy Florida [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	94	147
Duke Energy Florida [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	79	123
Duke Energy Florida [Member] \| Designated As Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	1
Duke Energy Florida [Member] \| Designated As Hedging Instrument [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	1
Duke Energy Florida [Member] \| Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	2	9
Location and fair value amounts of derivatives (Liability)	173	269
Duke Energy Florida [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	2
Duke Energy Florida [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	7
Duke Energy Florida [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	'
Location and fair value amounts of derivatives (Liability)	94	146
Duke Energy Florida [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	'
Location and fair value amounts of derivatives (Liability)	79	123
Duke Energy Ohio [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	314	220
Location and fair value amounts of derivatives (Liability)	290	199
Duke Energy Ohio [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	155	137
Duke Energy Ohio [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	159	81
Duke Energy Ohio [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	165	136
Duke Energy Ohio [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	120	55
Duke Energy Ohio [Member] \| Designated As Hedging Instrument [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	2
Duke Energy Ohio [Member] \| Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	'	2
Duke Energy Ohio [Member] \| Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	314	218
Location and fair value amounts of derivatives (Liability)	290	199
Duke Energy Ohio [Member] \| Nondesignated [Member] \| Interest Rate Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	1
Duke Energy Ohio [Member] \| Nondesignated [Member] \| Interest Rate Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	4	7
Duke Energy Ohio [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	21	31
Location and fair value amounts of derivatives (Liability)	6	4
Duke Energy Ohio [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Investments And Other Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	158	81
Location and fair value amounts of derivatives (Liability)	103	51
Duke Energy Ohio [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	134	106
Location and fair value amounts of derivatives (Liability)	160	132
Duke Energy Ohio [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Deferred Credits And Other Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	1	'
Location and fair value amounts of derivatives (Liability)	17	4
Duke Energy Indiana [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	14	10
Location and fair value amounts of derivatives (Liability)	'	63
Duke Energy Indiana [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	14	'
Duke Energy Indiana [Member] \| Nondesignated [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	14	10
Location and fair value amounts of derivatives (Liability)	'	63
Duke Energy Indiana [Member] \| Nondesignated [Member] \| Interest Rate Contracts [Member] \| Current Liabilities, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Liability)	'	63
Duke Energy Indiana [Member] \| Nondesignated [Member] \| Commodity Contracts [Member] \| Current Assets, Other [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Location and fair value amounts of derivatives (Asset)	$14	$10

Risk_Management_Derivative_Ins5

Risk Management, Derivative Instruments and Hedging Activities (Schedule of Offsetting Assets and Liabilities: Derivatives and Collateral Posted) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	$374		$264
Net amounts recognized on the Condensed Consolidated Balance Sheet	127	[1]	103	[1]
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	720		917
Net amounts recognized on the Condensed Consolidated Balance Sheet	473	[2]	756	[2]
Other Current Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	159		127
Gross amounts offset	-142		-114
Net amount subject to master netting	17		13
Amounts not subject to master netting	23		22
Net amounts recognized on the Condensed Consolidated Balance Sheet	40	[3]	35	[3]
Other Noncurrent Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	175		96
Gross amounts offset	-108		-54
Net amount subject to master netting	67		42
Amounts not subject to master netting	17		19
Net amounts recognized on the Condensed Consolidated Balance Sheet	84	[4]	61	[4]
Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	338		402
Gross amounts offset	-168		-151
Net amount subject to master netting	170		251
Amounts not subject to master netting	89		166
Net amounts recognized on the Condensed Consolidated Balance Sheet	259	[5]	417	[5]
Other Noncurrent Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	265		295
Gross amounts offset	-122		-90
Net amount subject to master netting	143		205
Amounts not subject to master netting	28		54
Net amounts recognized on the Condensed Consolidated Balance Sheet	171	[6]	259	[6]
Duke Energy Carolinas [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	4		12
Net amounts recognized on the Condensed Consolidated Balance Sheet	4	[7]	12	[7]
Duke Energy Carolinas [Member] \| Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Amounts not subject to master netting	3		6
Net amounts recognized on the Condensed Consolidated Balance Sheet	3	[5]	6	[5]
Duke Energy Carolinas [Member] \| Other Noncurrent Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Amounts not subject to master netting	1		6
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	[6]	6	[6]
Progress Energy [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	3		11
Net amounts recognized on the Condensed Consolidated Balance Sheet	'		11	[8]
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	285		440
Net amounts recognized on the Condensed Consolidated Balance Sheet	282	[9]	440	[9]
Progress Energy [Member] \| Other Current Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	1		3
Gross amounts offset	-1		'
Net amount subject to master netting	0		3
Net amounts recognized on the Condensed Consolidated Balance Sheet	0	[3]	3	[3]
Progress Energy [Member] \| Other Noncurrent Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	2		8
Gross amounts offset	-1		'
Net amount subject to master netting	1		8
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	[4]	8	[4]
Progress Energy [Member] \| Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	159		244
Gross amounts offset	-13		-22
Net amount subject to master netting	146		222
Net amounts recognized on the Condensed Consolidated Balance Sheet	146	[5]	222	[5]
Progress Energy [Member] \| Other Noncurrent Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	122		192
Gross amounts offset	-15		-36
Net amount subject to master netting	107		156
Amounts not subject to master netting	4		4
Net amounts recognized on the Condensed Consolidated Balance Sheet	111	[6]	160	[6]
Duke Energy Progress [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	1		2
Net amounts recognized on the Condensed Consolidated Balance Sheet	'		2	[8]
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	108		166
Net amounts recognized on the Condensed Consolidated Balance Sheet	107	[9]	166	[9]
Duke Energy Progress [Member] \| Other Current Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	'		1
Net amount subject to master netting	'		1
Net amounts recognized on the Condensed Consolidated Balance Sheet	'		1	[3]
Duke Energy Progress [Member] \| Other Noncurrent Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	1		1
Net amount subject to master netting	1		1
Net amounts recognized on the Condensed Consolidated Balance Sheet	1	[4]	1	[4]
Duke Energy Progress [Member] \| Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	65		97
Gross amounts offset	-3		-2
Net amount subject to master netting	62		95
Net amounts recognized on the Condensed Consolidated Balance Sheet	62	[5]	95	[5]
Duke Energy Progress [Member] \| Other Noncurrent Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	43		69
Gross amounts offset	-2		-7
Net amount subject to master netting	41		62
Net amounts recognized on the Condensed Consolidated Balance Sheet	41	[6]	62	[6]
Duke Energy Florida [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	2		9
Net amounts recognized on the Condensed Consolidated Balance Sheet	'		9
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	173		270
Net amounts recognized on the Condensed Consolidated Balance Sheet	171	[10]	270	[10]
Duke Energy Florida [Member] \| Other Current Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	1		2
Gross amounts offset	-1		'
Net amount subject to master netting	0		2
Net amounts recognized on the Condensed Consolidated Balance Sheet	0	[11]	2	[11]
Duke Energy Florida [Member] \| Other Noncurrent Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	1		7
Gross amounts offset	-1		'
Net amount subject to master netting	0		7
Net amounts recognized on the Condensed Consolidated Balance Sheet	0	[12]	7	[12]
Duke Energy Florida [Member] \| Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	94		147
Gross amounts offset	-10		-20
Net amount subject to master netting	84		127
Net amounts recognized on the Condensed Consolidated Balance Sheet	84	[13]	127	[13]
Duke Energy Florida [Member] \| Other Noncurrent Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	79		123
Gross amounts offset	-13		-29
Net amount subject to master netting	66		94
Net amounts recognized on the Condensed Consolidated Balance Sheet	66	[14]	94	[14]
Duke Energy Ohio [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	314		220
Net amounts recognized on the Condensed Consolidated Balance Sheet	70	[15]	59	[15]
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	290		199
Net amounts recognized on the Condensed Consolidated Balance Sheet	46	[9]	38	[9]
Duke Energy Ohio [Member] \| Other Current Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	155		137
Gross amounts offset	-141		-110
Net amount subject to master netting	14		27
Amounts not subject to master netting	'		2
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	[3]	29	[3]
Duke Energy Ohio [Member] \| Other Noncurrent Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	159		81
Gross amounts offset	-105		-51
Net amount subject to master netting	54		30
Net amounts recognized on the Condensed Consolidated Balance Sheet	54	[4]	30	[4]
Duke Energy Ohio [Member] \| Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	165		136
Gross amounts offset	-154		-125
Net amount subject to master netting	11		11
Amounts not subject to master netting	1		1
Net amounts recognized on the Condensed Consolidated Balance Sheet	12	[5]	12	[5]
Duke Energy Ohio [Member] \| Other Noncurrent Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	120		55
Gross amounts offset	-105		-51
Net amount subject to master netting	15		4
Amounts not subject to master netting	4		7
Net amounts recognized on the Condensed Consolidated Balance Sheet	19	[6]	11	[6]
Duke Energy Indiana [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	14		10
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	[16]	10	[16]
Derivative Liabilities Subject to Master Netting	'		'
Gross amounts recognized	'		63
Net amounts recognized on the Condensed Consolidated Balance Sheet	'		63	[2]
Duke Energy Indiana [Member] \| Other Current Assets [Member]	'		'
Derivative Assets Subject to Master Netting	'		'
Gross amounts recognized	14		'
Net amount subject to master netting	14		'
Amounts not subject to master netting	'		10
Net amounts recognized on the Condensed Consolidated Balance Sheet	14	[3]	10	[3]
Duke Energy Indiana [Member] \| Other Current Liabilities [Member]	'		'
Derivative Liabilities Subject to Master Netting	'		'
Amounts not subject to master netting	'		63
Net amounts recognized on the Condensed Consolidated Balance Sheet	'		$63	[5]

[1]	Included in Other within Current Assets and Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
[2]	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.
[3]	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.
[4]	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.
[5]	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.
[6]	Included in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.
[7]	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.
[8]	Included in Other Current Assets within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
[9]	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.
[10]	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Balance Sheets
[11]	Included in Other within Current Assets on the Condensed Balance Sheet.
[12]	Included in Other within Investments and Other Assets on the Condensed Balance Sheet.
[13]	Included in Other within Current Liabilities on the Condensed Balance Sheet.
[14]	Included in Other within Deferred Credits and Other Liabilities on the Condensed Balance Sheet.
[15]	Included in Other within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.
[16]	Included in Other within Current Assets on the Condensed Consolidated Balance Sheets.

Risk_Management_Derivative_Ins6

Risk Management, Derivative Instruments and Hedging Activities (Cash Flow Hedges - Location and Amount of PreTax Recognized in Comprehensive Income) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains and (losses) reclassified from AOCI into earnings	$379	$401	$1,127	$857
Designated As Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains (losses) recorded in AOCI	'	-3	72	-29
Pretax gains and (losses) recognized in earnings on derivatives	'	2	-2	'
Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recorded in AOCI - interest rate contracts	'	-4	71	-30
Total pretax gains and (losses) reclassified from AOCI into earnings	'	2	-2	'
Designated As Hedging Instrument [Member] \| Commodity Contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recorded in AOCI - commodity contracts	'	1	1	1
Duke Energy Carolinas [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recorded in AOCI - interest rate contracts	'	'	'	23
Total pretax gains and (losses) reclassified from AOCI into earnings	82	95	255	285
Progress Energy [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains and (losses) reclassified from AOCI into earnings	162	182	520	560
Progress Energy [Member] \| Designated As Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains (losses) recorded in AOCI	'	1	1	-10
Pretax gains and (losses) recognized in earnings on derivatives	-5	-2	-5	-12
Progress Energy [Member] \| Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recorded in AOCI - interest rate contracts	'	'	'	-11
Total pretax gains and (losses) reclassified from AOCI into earnings	-5	-2	-5	-12
Progress Energy [Member] \| Designated As Hedging Instrument [Member] \| Commodity Contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recorded in AOCI - commodity contracts	'	1	1	1
Duke Energy Progress [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains and (losses) reclassified from AOCI into earnings	52	52	147	156
Duke Energy Progress [Member] \| Designated As Hedging Instrument [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains (losses) recorded in AOCI	'	'	'	-7
Pretax gains and (losses) recognized in earnings on derivatives	'	'	'	-5
Duke Energy Progress [Member] \| Designated As Hedging Instrument [Member] \| Interest Rate Contracts [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recorded in AOCI - interest rate contracts	'	'	'	-7
Total pretax gains and (losses) reclassified from AOCI into earnings	'	'	'	-5
Duke Energy Florida [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains and (losses) reclassified from AOCI into earnings	46	62	138	194
Duke Energy Ohio [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains and (losses) reclassified from AOCI into earnings	14	21	50	70
Duke Energy Indiana [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Total pretax gains and (losses) reclassified from AOCI into earnings	$43	$35	$127	$105

Risk_Management_Derivative_Ins7

Risk Management, Derivative Instruments and Hedging Activities (Undesignated Contracts - Location and Amount of PreTax Gains and (Losses) Recognized in Income or As Regulatory Assets or Liabilities) (Details) (Nondesignated [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings	($78)	($190)	($195)	($154)
Pretax gains (losses) recognized as regulatory assets or liabilities	-11	80	27	92
Commodity Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	-29	61	-34	61
Commodity Contracts [Member] \| Regulatory Liability [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	6	12	10	34
Commodity Contracts [Member] \| Revenue Regulated Electric [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	3	-22	10	-22
Commodity Contracts [Member] \| Revenue Non Regulated Electric Natural Gas And Other [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-7	-28	-15	8
Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-68	-135	-157	-135
Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Non Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-2	'	-20	'
Commodity Contracts [Member] \| Other Income And Expense [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	'	-1	'	-1
Interest Rate Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	12	7	51	-3
Interest Rate Contracts [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - interest	-4	-4	-13	-4
Progress Energy [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings	-69	-148	-160	-408
Pretax gains (losses) recognized as regulatory assets or liabilities	-27	62	-21	-106
Progress Energy [Member] \| Commodity Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	-31	60	-34	-108
Progress Energy [Member] \| Commodity Contracts [Member] \| Revenue Regulated Electric [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	3	-9	10	-9
Progress Energy [Member] \| Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-68	-135	-157	-395
Progress Energy [Member] \| Interest Rate Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	4	2	13	2
Progress Energy [Member] \| Interest Rate Contracts [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - interest	-4	-4	-13	-4
Duke Energy Progress [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings	-24	-47	-52	-112
Pretax gains (losses) recognized as regulatory assets or liabilities	-8	17	-8	-32
Duke Energy Progress [Member] \| Commodity Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	-11	15	-18	-34
Duke Energy Progress [Member] \| Commodity Contracts [Member] \| Revenue Regulated Electric [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	3	-9	10	-9
Duke Energy Progress [Member] \| Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-24	-35	-53	-100
Duke Energy Progress [Member] \| Interest Rate Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	3	2	10	2
Duke Energy Progress [Member] \| Interest Rate Contracts [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - interest	-3	-3	-9	-3
Duke Energy Florida [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings	-46	-101	-108	-296
Pretax gains (losses) recognized as regulatory assets or liabilities	-18	45	-13	-74
Duke Energy Florida [Member] \| Commodity Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	-19	45	-16	-74
Duke Energy Florida [Member] \| Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-45	-100	-105	-295
Duke Energy Florida [Member] \| Interest Rate Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	1	'	3	'
Duke Energy Florida [Member] \| Interest Rate Contracts [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - interest	-1	-1	-3	-1
Duke Energy Ohio [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings	3	-42	-29	32
Pretax gains (losses) recognized as regulatory assets or liabilities	'	'	3	-1
Duke Energy Ohio [Member] \| Commodity Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	'	'	'	-2
Duke Energy Ohio [Member] \| Commodity Contracts [Member] \| Regulatory Liability [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	'	'	'	1
Duke Energy Ohio [Member] \| Commodity Contracts [Member] \| Revenue Non Regulated Electric Natural Gas And Other [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	5	-42	-8	33
Duke Energy Ohio [Member] \| Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Non Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	-2	'	-20	'
Duke Energy Ohio [Member] \| Interest Rate Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	'	'	3	'
Duke Energy Ohio [Member] \| Interest Rate Contracts [Member] \| Interest Expense [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - interest	'	'	-1	-1
Duke Energy Indiana [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings	'	'	1	2
Pretax gains (losses) recognized as regulatory assets or liabilities	14	15	44	28
Duke Energy Indiana [Member] \| Commodity Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	2	11	'	'
Duke Energy Indiana [Member] \| Commodity Contracts [Member] \| Regulatory Liability [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	'	6	10	33
Duke Energy Indiana [Member] \| Commodity Contracts [Member] \| Revenue Regulated Electric [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	'	'	1	'
Duke Energy Indiana [Member] \| Commodity Contracts [Member] \| Fuel Used In Electric Generation And Purchased Power Regulated [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized in earnings - commodities	'	'	'	2
Duke Energy Indiana [Member] \| Interest Rate Contracts [Member] \| Regulatory Asset [Member]	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Pretax gains (losses) recognized as regulatory assets or liabilities	$6	$4	$34	($5)

Risk_Management_Derivative_Ins8

Risk Management, Derivative Instruments and Hedging Activities (Derivative Instruments That Contain Credit-Risk Related Contingent Features and Cash Collateral) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'	'
Aggregate fair value amounts of derivative instruments in a net liability position	$481	$466
Collateral aready posted	138	163
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered at the end of the reporting period	200	230
Information Regarding Cash Collateral Under Master Netting Arrangements	'	'
Amounts offset against derivative positions on the net condensed Consolidated Balance Sheets, Receivables	40	73
Derivative, collateral, right to reclaim cash - not offset against net derivative	101	93
Progress Energy [Member]	'	'
Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'	'
Aggregate fair value amounts of derivative instruments in a net liability position	211	286
Collateral aready posted	26	59
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered at the end of the reporting period	185	227
Information Regarding Cash Collateral Under Master Netting Arrangements	'	'
Amounts offset against derivative positions on the net condensed Consolidated Balance Sheets, Receivables	26	58
Derivative, collateral, right to reclaim cash - not offset against net derivative	'	1
Duke Energy Progress [Member]	'	'
Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'	'
Aggregate fair value amounts of derivative instruments in a net liability position	82	108
Collateral aready posted	5	9
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered at the end of the reporting period	77	99
Information Regarding Cash Collateral Under Master Netting Arrangements	'	'
Amounts offset against derivative positions on the net condensed Consolidated Balance Sheets, Receivables	5	9
Duke Energy Florida [Member]	'	'
Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'	'
Aggregate fair value amounts of derivative instruments in a net liability position	129	178
Collateral aready posted	21	50
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered at the end of the reporting period	108	128
Information Regarding Cash Collateral Under Master Netting Arrangements	'	'
Amounts offset against derivative positions on the net condensed Consolidated Balance Sheets, Receivables	21	49
Derivative, collateral, right to reclaim cash - not offset against net derivative	'	1
Duke Energy Ohio [Member]	'	'
Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'	'
Aggregate fair value amounts of derivative instruments in a net liability position	268	176
Collateral aready posted	106	104
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered at the end of the reporting period	15	2
Information Regarding Cash Collateral Under Master Netting Arrangements	'	'
Amounts offset against derivative positions on the net condensed Consolidated Balance Sheets, Receivables	13	15
Derivative, collateral, right to reclaim cash - not offset against net derivative	92	92
Duke Energy Indiana [Member]	'	'
Information Regarding Cash Collateral Under Master Netting Arrangements	'	'
Derivative, collateral, right to reclaim cash - not offset against net derivative	$3	'

Recovered_Sheet1

Fair Value Of Financial Assets and Liabilities (Narrative) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Auction Rate Securities [Abstract]	'	'	'	'
Settlements	($5)	($10)	($8)	($73)
Interest Rate Current [Member]	'	'	'	'
Auction Rate Securities [Abstract]	'	'	'	'
Level 3 ARS assumptions	0.20%	'	0.20%	'
Auction Rate Securities [Member] \| Discounted Cash Flow [Member] \| Risk Adjusted Discount Rates [Member]	'	'	'	'
Auction Rate Securities [Abstract]	'	'	'	'
Level 3 ARS assumptions	5.60%	'	5.60%	'
Duke Energy Carolinas [Member]	'	'	'	'
Auction Rate Securities [Abstract]	'	'	'	'
Settlements	'	$2	$8	($6)

Recovered_Sheet2

Fair Value Of Financial Assets and Liabilities (Fair Value Measurement Amounts for Assets and Liabilities) (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

In Millions, unless otherwise specified

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Auction Rate Securities [Member]

NDTF [Member]

Other Classification [Member]

Duke Energy Carolinas [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Level 3 [Member]

Equity Securities [Member]

Debt Securities [Member]

Equity Securities [Member]

Debt Securities [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Auction Rate Securities [Member]

NDTF [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

NDTF [Member]

Other Classification [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

NDTF [Member]

Other Classification [Member]

Level 1 [Member]

Level 2 [Member]

NDTF [Member]

Other Classification [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Other Classification [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Equity Securities [Member]

Debt Securities [Member]

Equity Securities [Member]

Debt Securities [Member]

Equity Securities [Member]

Debt Securities [Member]

Equity Securities [Member]

Debt Securities [Member]

Equity Securities [Member]

Debt Securities [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 3 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Level 1 [Member]

Level 2 [Member]

Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]

Investments

$25

[1]

$29

[1]

$25

[1]

$29

[1]

$3,280

$2,837

$3,199

$2,762

$59

$54

$22

$21

$1,525

$1,405

$392

$317

$1,083

$1,040

$50

$48

$93

[2]

$72

[2]

$83

[2]

$63

[2]

$10

[2]

$414

[3]

$602

[3]

$57

[3]

$40

[3]

$357

[3]

$562

[3]

[4]

$1,790

$1,592

$1,715

$1,523

$53

$48

$22

$21

$883

$762

$220

$155

$613

$559

$50

$48

$1,489

$1,245

$1,483

$1,239

$642

$643

$172

$162

$470

$481

$55

[5]

$57

[5]

$19

[5]

$17

[5]

$36

[5]

$40

[5]

$985

$811

$985

$811

$440

$448

$112

$119

$328

$329

[5]

$505

$435

$499

$429

$202

$194

$60

$43

$142

$151

$39

[6]

$43

[6]

$37

[6]

$40

[6]

$60

[1]

$49

[1]

$60

[1]

$49

[1]

$28

[1]

$29

[1]

$28

[1]

$29

[1]

Derivative assets

127

[2]

103

[2]

[7]

[8]

[9]

Total assets

5,464

5,048

3,763

3,200

1,531

1,687

170

161

2,676

2,357

1,935

1,678

666

607

2,186

1,956

1,674

1,418

512

538

1,427

1,264

1,099

933

328

331

746

681

561

475

185

206

102

Derivative liabilities

-473

[10]

-756

[10]

-15

[10]

-17

[10]

-347

[10]

-591

[10]

-111

[10]

-148

[10]

-4

[11]

-12

[11]

-4

[11]

-12

[11]

-282

[12]

-440

[12]

-282

[12]

-402

[12]

-38

[12]

-107

[12]

-166

[12]

-107

[12]

-128

[12]

-38

[12]

-171

[13]

-270

[13]

-171

[13]

-270

[13]

-46

[12]

-38

[12]

-14

[12]

-15

[12]

-5

[12]

-8

[12]

-27

[12]

-15

[12]

-63

[10]

-63

[10]

Net assets

$4,991

$4,292

$3,748

$3,183

$1,184

$1,096

$59

$13

$2,672

$2,345

$1,935

$1,678

$666

$607

$71

$60

$1,904

$1,516

$1,674

$1,418

$230

$136

($38)

$1,320

$1,098

$1,099

$933

$221

$203

($38)

$575

$411

$561

$475

$14

($64)

$24

$21

$35

$33

($5)

($6)

$102

$25

$60

$49

$28

($34)

$14

$10

[1]

Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

[2]

Included in Other within Current Assets and Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.

[3]

Included in Other within Investments and Other Assets and Short-term Investments on the Condensed Consolidated Balance Sheets.

[4]

Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.

[5]

Included in Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.

[6]

Included in Other within Investments and Other Assets in the Condensed Balance Sheets.

[7]

Included in Other Current Assets within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.

[8]

Included in Other within Current Assets and Other within Investments and Other Assets in the Condensed Consolidated Balance Sheets.

[9]

Included in Other within Current Assets on the Condensed Consolidated Balance Sheets.

[10]

Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.

[11]

Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.

[12]

Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Consolidated Balance Sheets.

[13]

Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities in the Condensed Balance Sheets

Fair_Value_Of_Financial_Assets2

Fair Value Of Financial Assets and Liabilities (Reconciliation of Assets and Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs) (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Jun. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Jun. 30, 2013

Dec. 31, 2012

Jun. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Jun. 30, 2013

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Available For Sale Auction Rate Securities [Member]

Available For Sale Ndtf Investments [Member]

Derivative [Member]

Duke Energy Carolinas [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Available For Sale Auction Rate Securities [Member]

Available For Sale Ndtf Investments [Member]

Derivative [Member]

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]

Beginning balance

$10

$86

$13

$85

$26

$29

$71

$41

$71

$64

$69

$53

($87)

($19)

($85)

($39)

$70

$60

$65

$12

$71

$64

$69

$53

($12)

($4)

($35)

($30)

($38)

($24)

($35)

($28)

($38)

($24)

($19)

($2)

($6)

($3)

$18

$22

$10

Amounts acquired in Progress Energy merger

-30

Revenue, regulated electric

Revenue, non-regulated electric, natural gas

-6

-13

-9

-6

-13

-9

-6

-4

-5

Gains on available for sale securities and other

-1

Purchases

Sales

-2

-5

-2

-5

-2

-5

-2

-5

Issuances

-24

-14

-16

Settlements

-5

-10

-8

-73

-2

-3

-39

-3

-10

-5

-34

-6

-8

-1

-10

-16

-23

-45

Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory asset or liability

-1

-4

-1

-6

-2

-1

-5

-2

Transfers in and/or out of level 3

Ending balance

-38

-75

-38

-75

-12

-4

-12

-4

-36

-6

-8

-6

-8

Revenue, regulated electric

-4

Revenue, non regulated electric and other - non-regulated

-2

-26

-2

-26

-3

-16

Total

($21)

($4)

$10

($3)

($16)

Fair_Value_Of_Financial_Assets3

Fair Value Of Financial Assets and Liabilities (Quantitative Level 3 Fair Value Disclosure) (Details) (USD $)	9 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	($43)	($53)
Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	10.36	9.99
Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	3.47	2.33
FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	-4	-23
FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	48.34	48.69
FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	25.79	25.83
Financial Transmission Rights [Member] \| RTO Market Pricing [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	15	11
Financial Transmission Rights [Member] \| RTO Market Pricing [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price FTR	10.86	39.22
Financial Transmission Rights [Member] \| RTO Market Pricing [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price FTR	-1.53	23.63
Commodity Power Contracts [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	5	-8
Commodity Power Contracts [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	54.19	77.96
Commodity Power Contracts [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	26.2	24.82
Commodity Capacity Contracts [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	-3	-3
Commodity Capacity Contracts [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per Mwd	'	105.36
Commodity Capacity Contracts [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per Mwd	95.16	95.16
Commodity Capacity Option Contracts [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	4	3
Commodity Capacity Option Contracts [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per Mwd	100.8	77.96
Commodity Capacity Option Contracts [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per Mwd	29.3	4.68
Derivative Financial Instruments Liabilities Reserves [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	-12	-12
Duke Energy Carolinas [Member] \| FERC Mitigation Power Sale Agreements [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	-4	'
Duke Energy Carolinas [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	'	-12
Duke Energy Carolinas [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	48.34	48.69
Duke Energy Carolinas [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	25.79	25.83
Progress Energy [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	'	-27
Progress Energy [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	'	4.45
Progress Energy [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	'	4.07
Progress Energy [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	'	-11
Progress Energy [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	'	48.69
Progress Energy [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	'	25.83
Duke Energy Progress [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	'	-27
Duke Energy Progress [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	'	4.45
Duke Energy Progress [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	'	4.07
Duke Energy Progress [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	'	-11
Duke Energy Progress [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	'	48.69
Duke Energy Progress [Member] \| FERC Mitigation Power Sale Agreements [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	'	25.83
Duke Energy Ohio [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	-9	5
Duke Energy Ohio [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	4.55	4.51
Duke Energy Ohio [Member] \| Commodity Natural Gas Hedges [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair Value Inputs Price Per MMBtu	3.47	3.3
Duke Energy Ohio [Member] \| Financial Transmission Rights [Member] \| RTO Market Pricing [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	1	1
Duke Energy Ohio [Member] \| Financial Transmission Rights [Member] \| RTO Market Pricing [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price FTR	0.46	39.22
Duke Energy Ohio [Member] \| Financial Transmission Rights [Member] \| RTO Market Pricing [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price FTR	-0.09	27.17
Duke Energy Ohio [Member] \| Commodity Power Contracts [Member] \| Discounted Cash Flow [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	13	-1
Duke Energy Ohio [Member] \| Commodity Power Contracts [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	54.19	57.5
Duke Energy Ohio [Member] \| Commodity Power Contracts [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price per MWh	26.2	25.9
Duke Energy Ohio [Member] \| Derivative Financial Instruments Liabilities Reserves [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	-11	-11
Duke Energy Indiana [Member] \| Financial Transmission Rights [Member] \| RTO Market Pricing [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Net derivative asset (liability)	$14	$10
Duke Energy Indiana [Member] \| Financial Transmission Rights [Member] \| RTO Market Pricing [Member] \| Maximum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price FTR	10.86	35.43
Duke Energy Indiana [Member] \| Financial Transmission Rights [Member] \| RTO Market Pricing [Member] \| Minimum [Member]	'	'
Net Derivative Asset (Liability) Fair Value Inputs [Line Items]	'	'
Fair value inputs, price FTR	-1.53	23.63

Fair_Value_Of_Financial_Assets4

Fair Value Of Financial Assets and Liabilities (Additional Fair Value Disclosure) (Details) (USD $)	9 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	$42,142		$44,001
Debt of variable interest entities	1,265		852
Long-term debt	39,709	[1]	39,461	[1]
Duke Energy Carolinas [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	9,445		10,096
Debt of variable interest entities	300		300
Long-term debt	8,739	[2]	8,741	[2]
Progress Energy [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	14,989		16,563
Long-term debt	13,815		14,428
Duke Energy Progress [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	5,053		5,277
Long-term debt	4,936		4,840
Duke Energy Florida [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	5,424		6,222
Long-term debt	4,887		5,320
Duke Energy Ohio [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	2,263		2,117
Long-term debt	2,188		1,997
Duke Energy Indiana [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Long-term debt, fair value	4,143		4,268
Long-term debt	$3,798		$3,702

[1]	Includes book value of Non-recourse long-term debt of variable interest entities of $1,265 million and $852 million September 30, 2013 and December 31, 2012, respectively.
[2]	Includes book value of Non-recourse long-term debt of variable interest entities of $300 million at both September 30, 2013 and December 31, 2012, respectively.

Investments_in_Debt_and_Equity2

Investments in Debt and Equity Securities (Narrative) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Schedule of Investments [Line Items]	'	'
Short-term investments	$118	$333
Trading Securities	$17	$33

Investments_in_Debt_and_Equity3

Investments in Debt and Equity Securities (Available-For-Sale Investments) (Details) (USD $)	3 Months Ended			9 Months Ended			12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012	Dec. 31, 2012
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	$1,630		'	$1,216
Gross Unrealized Holding Losses	'		'	50		'	30
Estimated Fair Value	5,323		'	5,323		'	4,932
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]	'		'	'		'	'
Realized gains	72		30	135		80	'
Realized losses	16		12	38		14	'
Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1,605		'	1,199
Gross Unrealized Holding Losses	'		'	38		'	23
Estimated Fair Value	4,806		'	4,806		'	4,263
Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	25	[1]	'	17	[1]
Gross Unrealized Holding Losses	'		'	12	[1]	'	7	[1]
Estimated Fair Value	517	[1]	'	517	[1]	'	669	[1]
Cash and Cash Equivalents [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	111		'	111		'	105
Cash and Cash Equivalents [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	21		'	21		'	17
Equity Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1,560		'	1,132
Gross Unrealized Holding Losses	'		'	13		'	19
Estimated Fair Value	3,280		'	3,280		'	2,837
Equity Securities [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	22		'	10
Estimated Fair Value	83		'	83		'	63
Corporate Debt Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	9		'	21
Gross Unrealized Holding Losses	'		'	6		'	1
Estimated Fair Value	323		'	323		'	338
Corporate Debt Securities [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1		'	2
Gross Unrealized Holding Losses	'		'	2		'	'
Estimated Fair Value	178		'	178		'	381
Municipal Bonds [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	5		'	12
Gross Unrealized Holding Losses	'		'	7		'	1
Estimated Fair Value	213		'	213		'	194
Municipal Bonds [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	2		'	4
Gross Unrealized Holding Losses	'		'	2		'	1
Estimated Fair Value	80		'	80		'	70
US Treasury and Government [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	14		'	24
Gross Unrealized Holding Losses	'		'	8		'	1
Estimated Fair Value	712		'	712		'	625
US Treasury and Government [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	38		'	38		'	23
Auction Rate Securities [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Losses	'		'	7		'	6
Estimated Fair Value	25		'	25		'	29
Other Debt Obligations [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	17		'	10
Gross Unrealized Holding Losses	'		'	4		'	1
Estimated Fair Value	167		'	167		'	164
Other Debt Obligations [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	1
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	92		'	92		'	86
Duke Energy Carolinas [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	854		'	632
Gross Unrealized Holding Losses	'		'	20		'	9
Estimated Fair Value	2,670		'	2,670		'	2,364
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]	'		'	'		'	'
Realized gains	49		19	95		65	'
Realized losses	1		5	11		7	'
Duke Energy Carolinas [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	854		'	632
Gross Unrealized Holding Losses	'		'	19		'	8
Estimated Fair Value	2,667		'	2,667		'	2,361
Duke Energy Carolinas [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Losses	'		'	1	[2]	'	1	[2]
Estimated Fair Value	3	[2]	'	3	[2]	'	3	[2]
Duke Energy Carolinas [Member] \| Cash and Cash Equivalents [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	46		'	46		'	40
Duke Energy Carolinas [Member] \| Equity Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	828		'	600
Gross Unrealized Holding Losses	'		'	5		'	5
Estimated Fair Value	1,790		'	1,790		'	1,592
Duke Energy Carolinas [Member] \| Corporate Debt Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	4		'	11
Gross Unrealized Holding Losses	'		'	5		'	1
Estimated Fair Value	236		'	236		'	250
Duke Energy Carolinas [Member] \| Municipal Bonds [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	2
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	52		'	52		'	40
Duke Energy Carolinas [Member] \| US Treasury and Government [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	5		'	10
Gross Unrealized Holding Losses	'		'	4		'	'
Estimated Fair Value	396		'	396		'	304
Duke Energy Carolinas [Member] \| Auction Rate Securities [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Losses	'		'	1		'	1
Estimated Fair Value	3		'	3		'	3
Duke Energy Carolinas [Member] \| Other Debt Obligations [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	17		'	9
Gross Unrealized Holding Losses	'		'	4		'	2
Estimated Fair Value	147		'	147		'	135
Progress Energy [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	752		'	570
Gross Unrealized Holding Losses	'		'	20		'	15
Estimated Fair Value	2,196		'	2,196		'	1,959
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]	'		'	'		'	'
Realized gains	22		8	37		23	'
Realized losses	11		6	20		12	'
Progress Energy [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	751		'	567
Gross Unrealized Holding Losses	'		'	19		'	15
Estimated Fair Value	2,139		'	2,139		'	1,902
Progress Energy [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1	[1]	'	3	[1]
Gross Unrealized Holding Losses	'		'	1	[1]	'	'
Estimated Fair Value	57	[1]	'	57	[1]	'	57	[1]
Progress Energy [Member] \| Cash and Cash Equivalents [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	65		'	65		'	65
Progress Energy [Member] \| Cash and Cash Equivalents [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	21		'	21		'	17
Progress Energy [Member] \| Equity Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	732		'	532
Gross Unrealized Holding Losses	'		'	8		'	14
Estimated Fair Value	1,490		'	1,490		'	1,245
Progress Energy [Member] \| Corporate Debt Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	5		'	9
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	87		'	87		'	89
Progress Energy [Member] \| Municipal Bonds [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	5		'	11
Gross Unrealized Holding Losses	'		'	6		'	1
Estimated Fair Value	161		'	161		'	154
Progress Energy [Member] \| Municipal Bonds [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1		'	3
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	36		'	36		'	40
Progress Energy [Member] \| US Treasury and Government [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	9		'	14
Gross Unrealized Holding Losses	'		'	4		'	'
Estimated Fair Value	316		'	316		'	321
Progress Energy [Member] \| Other Debt Obligations [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	1
Estimated Fair Value	20		'	20		'	28
Duke Energy Progress [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	487		'	363
Gross Unrealized Holding Losses	'		'	15		'	11
Estimated Fair Value	1,437		'	1,437		'	1,278
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]	'		'	'		'	'
Realized gains	7		4	15		14	'
Realized losses	2		2	6		5	'
Duke Energy Progress [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	487		'	363
Gross Unrealized Holding Losses	'		'	15		'	11
Estimated Fair Value	1,435		'	1,435		'	1,275
Duke Energy Progress [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	2	[1]	'	2	[1]	'	3	[1]
Duke Energy Progress [Member] \| Cash and Cash Equivalents [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	30		'	30		'	55
Duke Energy Progress [Member] \| Cash and Cash Equivalents [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	2		'	2		'	3
Duke Energy Progress [Member] \| Equity Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	472		'	337
Gross Unrealized Holding Losses	'		'	7		'	11
Estimated Fair Value	985		'	985		'	811
Duke Energy Progress [Member] \| Corporate Debt Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	5		'	8
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	83		'	83		'	78
Duke Energy Progress [Member] \| Municipal Bonds [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	2		'	4
Gross Unrealized Holding Losses	'		'	4		'	'
Estimated Fair Value	103		'	103		'	80
Duke Energy Progress [Member] \| US Treasury and Government [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	8		'	13
Gross Unrealized Holding Losses	'		'	3		'	'
Estimated Fair Value	225		'	225		'	241
Duke Energy Progress [Member] \| Other Debt Obligations [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	1
Estimated Fair Value	9		'	9		'	10
Duke Energy Florida [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	265		'	207
Gross Unrealized Holding Losses	'		'	5		'	4
Estimated Fair Value	745		'	745		'	668
Available-for-sale Securities, Gross Realized Gain (Loss) [Abstract]	'		'	'		'	'
Realized gains	14		4	22		9	'
Realized losses	9		4	13		7	'
Duke Energy Florida [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	264		'	204
Gross Unrealized Holding Losses	'		'	4		'	4
Estimated Fair Value	704		'	704		'	627
Duke Energy Florida [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1	[3]	'	3	[3]
Gross Unrealized Holding Losses	'		'	1	[3]	'	'
Estimated Fair Value	41	[3]	'	41	[3]	'	41	[3]
Duke Energy Florida [Member] \| Cash and Cash Equivalents [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	35		'	35		'	10
Duke Energy Florida [Member] \| Cash and Cash Equivalents [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Estimated Fair Value	4		'	4		'	1
Duke Energy Florida [Member] \| Equity Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	260		'	194
Gross Unrealized Holding Losses	'		'	1		'	4
Estimated Fair Value	505		'	505		'	434
Duke Energy Florida [Member] \| Corporate Debt Securities [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	1
Estimated Fair Value	4		'	4		'	11
Duke Energy Florida [Member] \| Municipal Bonds [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	3		'	7
Gross Unrealized Holding Losses	'		'	2		'	'
Estimated Fair Value	58		'	58		'	74
Duke Energy Florida [Member] \| Municipal Bonds [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1		'	3
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	37		'	37		'	40
Duke Energy Florida [Member] \| US Treasury and Government [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	1		'	1
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	91		'	91		'	80
Duke Energy Florida [Member] \| Other Debt Obligations [Member] \| Ndtf [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	1
Estimated Fair Value	11		'	11		'	18
Duke Energy Indiana [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	19		'	10
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	88		'	88		'	78
Duke Energy Indiana [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	19	[1]	'	10	[1]
Gross Unrealized Holding Losses	'		'	1	[1]	'	'
Estimated Fair Value	88	[1]	'	88	[1]	'	78	[1]
Duke Energy Indiana [Member] \| Equity Securities [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	19		'	9
Estimated Fair Value	60		'	60		'	50
Duke Energy Indiana [Member] \| Municipal Bonds [Member] \| Other Classification [Member]	'		'	'		'	'
Schedule of Available-for-sale Securities [Line Items]	'		'	'		'	'
Gross Unrealized Holding Gains	'		'	'		'	1
Gross Unrealized Holding Losses	'		'	1		'	'
Estimated Fair Value	$28		'	$28		'	$28

[1]	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
[2]	These amounts are recorded in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheets.
[3]	These amounts are recorded in Other within Investments and Other Assets on the Condensed Balance Sheets.

Investments_in_Debt_and_Equity4

Investments in Debt and Equity Securities (Maturities) (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified	Sep. 30, 2013
Debt Instrument [Line Items]	'
1 year	$185
1 through 5 years	394
6 to 10 years	434
Thereafter	790
Total	1,803
Duke Energy Carolinas [Member]	'
Debt Instrument [Line Items]	'
1 year	23
1 through 5 years	175
6 to 10 years	223
Thereafter	410
Total	831
Progress Energy [Member]	'
Debt Instrument [Line Items]	'
1 year	14
1 through 5 years	162
6 to 10 years	150
Thereafter	294
Total	620
Duke Energy Progress [Member]	'
Debt Instrument [Line Items]	'
1 year	6
1 through 5 years	125
6 to 10 years	88
Thereafter	201
Total	420
Duke Energy Florida [Member]	'
Debt Instrument [Line Items]	'
1 year	8
1 through 5 years	37
6 to 10 years	62
Thereafter	94
Total	201
Duke Energy Indiana [Member]	'
Debt Instrument [Line Items]	'
1 year	2
1 through 5 years	21
6 to 10 years	4
Thereafter	1
Total	$28

Variable_Interest_Entities_Nar

Variable Interest Entities (Narrative) (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2010

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Jan. 12, 2012

Sep. 30, 2013

In Millions, unless otherwise specified

Minimum [Member]

DukeNet And Alinda Capital Partners LLC Ownership In The New Joint Venture [Member]

Cinergy Receivables [Member]

Other VIEs [Member]

FPC Capital I Trust [Member]

Duke Energy Carolinas [Member]

Duke Energy Progress [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Minimum [Member]

Maximum [Member]

Variable Interest Entity, Not Primary Beneficiary [Member]

DERF [Member]

Cinergy Receivables [Member]

Variable Interest Entity, Primary Beneficiary [Member]

Variable Interest Entity [Line Items]

Borrowing limitation for CRC

75.00%

Minimum Equity Balance required by Cinergy Receivables

Subordinated retained interest limitation of the total proceeds

10.00%

20.00%

Secured credit facility of variable interest entities

400

Fixed rate used when selling receivables

1.00%

Equity ownership interest rate

62.50%

Senior secured credit facility

150

Line of credit facility, expiration date

1-Nov-17

1-Nov-13

1-Oct-16

Ownership interest in OVEC

9.00%

Debt instrument, face amount

$3,771

$300

$548

$450

$500

Variable_Interest_Entities_Con

Variable Interest Entities (Consolidated VIEs) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Cash and cash equivalents	$2,166		$1,424	$1,761	$2,110
Restricted receivables of VIEs	1,258		1,201	'	'
Other current assets	2,191		2,425	'	'
Intangibles, net	351		372	'	'
Restricted other assets of VIEs	52		62	'	'
Investments and other assets	2,361		2,399	'	'
Property, plant and equipment, cost	1,679		1,558	'	'
Accumulated depreciation and amortization	-33,136		-31,969	'	'
Other deferred debits	178		178	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Accounts payable	1,819		2,444	'	'
Non-recourse notes payable	325		312	'	'
Current maturities of long-term debt	2,307		3,110	'	'
Other current liabilities	2,330		2,511	'	'
Non-recourse long-term debt	1,265		852	'	'
Deferred income taxes	11,489		10,490	'	'
Asset retirement obligation	5,341		5,169	'	'
Other liabilities	1,789		2,221	'	'
Noncontrolling interests	72		78	'	'
Cinergy Receivables [Member] \| Variable Interest Entity, Primary Beneficiary [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Restricted receivables of VIEs	527		534	'	'
Total assets	527		534	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Non-recourse notes payable	325		312	'	'
Total liabilities	325		312	'	'
Net assets of consolidated VIEs	202		222	'	'
CinCap V [Member] \| Variable Interest Entity, Primary Beneficiary [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Restricted receivables of VIEs	17		15	'	'
Other current assets	5		4	'	'
Restricted other assets of VIEs	40		52	'	'
Investments and other assets	12		10	'	'
Total assets	74		81	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Current maturities of long-term debt	14		13	'	'
Other current liabilities	5		4	'	'
Non-recourse long-term debt	37		48	'	'
Other liabilities	12		10	'	'
Total liabilities	68		75	'	'
Net assets of consolidated VIEs	6		6	'	'
Renewables [Member] \| Variable Interest Entity, Primary Beneficiary [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Restricted receivables of VIEs	11		16	'	'
Other current assets	199		133	'	'
Intangibles, net	11		12	'	'
Restricted other assets of VIEs	12		2	'	'
Investments and other assets	4		'	'	'
Property, plant and equipment, cost	1,663		1,543	'	'
Accumulated depreciation and amortization	-146		-98	'	'
Other deferred debits	34		40	'	'
Total assets	1,788		1,648	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Accounts payable	3		1	'	'
Taxes accrued	12		62	'	'
Current maturities of long-term debt	62		459	'	'
Other current liabilities	26		25	'	'
Non-recourse long-term debt	928		504	'	'
Deferred income taxes	255		154	'	'
Asset retirement obligation	25		23	'	'
Other liabilities	102		39	'	'
Total liabilities	1,413		1,267	'	'
Net assets of consolidated VIEs	375		381	'	'
Other VIEs [Member] \| Variable Interest Entity, Primary Beneficiary [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Restricted receivables of VIEs	'		-1	'	'
Other current assets	2		2	'	'
Investments and other assets	3		2	'	'
Property, plant and equipment, cost	16		15	'	'
Accumulated depreciation and amortization	-5		-5	'	'
Total assets	16		13	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Net assets of consolidated VIEs	16		13	'	'
Total Consolidated VIE [Member] \| Variable Interest Entity, Primary Beneficiary [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Restricted receivables of VIEs	1,258		1,201	'	'
Other current assets	206		139	'	'
Intangibles, net	11		12	'	'
Restricted other assets of VIEs	52		54	'	'
Investments and other assets	19		12	'	'
Property, plant and equipment, cost	1,679		1,558	'	'
Accumulated depreciation and amortization	-151		-103	'	'
Other deferred debits	34		40	'	'
Total assets	3,108		2,913	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Accounts payable	3		1	'	'
Non-recourse notes payable	325		312	'	'
Taxes accrued	12		62	'	'
Current maturities of long-term debt	76		472	'	'
Other current liabilities	31		29	'	'
Non-recourse long-term debt	1,265		852	'	'
Deferred income taxes	255		154	'	'
Asset retirement obligation	25		23	'	'
Other liabilities	114		49	'	'
Total liabilities	2,106		1,954	'	'
Net assets of consolidated VIEs	1,002		959	'	'
Duke Energy Carolinas [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Cash and cash equivalents	25		19	314	289
Restricted receivables of VIEs	703		637	'	'
Other current assets	474		439	'	'
Investments and other assets	845		934	'	'
Accumulated depreciation and amortization	-11,731		-11,437	'	'
Other deferred debits	45		71	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Accounts payable	451		599	'	'
Current maturities of long-term debt	447		406	'	'
Other current liabilities	461		490	'	'
Non-recourse long-term debt	300		300	'	'
Deferred income taxes	5,537		5,181	'	'
Asset retirement obligation	2,053		1,959	'	'
Other liabilities	732		924	'	'
Duke Energy Carolinas [Member] \| DERF [Member] \| Variable Interest Entity, Primary Beneficiary [Member]	'		'	'	'
Variable Interest Entity Consolidated Carrying Amount Assets [Abstract]	'		'	'	'
Restricted receivables of VIEs	703	[1]	637	'	'
Total assets	703	[1]	637	'	'
Variable Interest Entity Consolidated Carrying Amount Liabilities [Abstract]	'		'	'	'
Non-recourse long-term debt	300	[1]	300	'	'
Total liabilities	300	[1]	300	'	'
Net assets of consolidated VIEs	$403	[1]	$337	'	'

[1]	Duke Energy Receivables Finance Company, LLC (DERF) is a wholly owned limited liability company of Duke Energy Carolinas.

Variable_Interest_Entities_Sch

Variable Interest Entities (Schedule of Non-Consolidated VIEs) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013		Dec. 31, 2012
Variable Interest Entity [Line Items]	'		'
Investments in equity method unconsolidated affiliates	$511		$483
Investments and other assets	2,361		2,399
Intangibles	351		372
Other current liabilities	2,330		2,511
Deferred credits and other liabilities	26,712		26,442
Long-term debt	39,709	[1]	39,461	[1]
Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments in equity method unconsolidated affiliates	290		292
Investments and other assets	4		11
Intangibles	100		104
Total assets	394		407
Other current liabilities	2		3
Deferred credits and other liabilities	15		336
Total liabilities	17		339
Net assets (liabilities)	377		68
DukeNet [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments in equity method unconsolidated affiliates	113		118
Total assets	113		118
Net assets (liabilities)	113		118
Renewables [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments in equity method unconsolidated affiliates	152		147
Total assets	152		147
Net assets (liabilities)	152		147
Other VIEs [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments in equity method unconsolidated affiliates	25		27
Investments and other assets	4		2
Intangibles	100		104
Total assets	129		133
Other current liabilities	2		3
Deferred credits and other liabilities	15		17
Total liabilities	17		20
Net assets (liabilities)	112		113
FPC Capital I Trust [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	'		9	[2]
Total assets	'		9
Deferred credits and other liabilities	'		319	[2]
Total liabilities	'		319
Net assets (liabilities)	'		-310
Duke Energy Carolinas [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	845		934
Other current liabilities	461		490
Deferred credits and other liabilities	11,228		10,602
Long-term debt	8,739	[3]	8,741	[3]
Progress Energy [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	531		530
Other current liabilities	1,177		1,118
Deferred credits and other liabilities	9,313		9,755
Long-term debt	13,815		14,428
Progress Energy [Member] \| FPC Capital I Trust [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	'		9
Deferred credits and other liabilities	'		274
Duke Energy Progress [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	297		251
Other current liabilities	440		517
Deferred credits and other liabilities	6,463		6,451
Long-term debt	4,936		4,840
Duke Energy Florida [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	176		182
Other current liabilities	667		534
Deferred credits and other liabilities	3,843		3,934
Long-term debt	4,887		5,320
Duke Energy Ohio [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	98		75
Intangibles	120		129
Other current liabilities	114		126
Deferred credits and other liabilities	2,545		2,473
Long-term debt	2,188		1,997
Duke Energy Ohio [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Receivables	75		97
Intangibles	98		104
Total assets	173		201
Net assets (liabilities)	173		201
Duke Energy Indiana [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Investments and other assets	160		122
Intangibles	33		41
Other current liabilities	101		165
Deferred credits and other liabilities	2,294		2,005
Long-term debt	3,798		3,702
Duke Energy Indiana [Member] \| Variable Interest Entity, Not Primary Beneficiary [Member]	'		'
Variable Interest Entity [Line Items]	'		'
Receivables	114		116
Total assets	114		116
Net assets (liabilities)	$114		$116

[1]	Includes book value of Non-recourse long-term debt of variable interest entities of $1,265 million and $852 million September 30, 2013 and December 31, 2012, respectively.
[2]	The entire balance of Investments and other assets and $274 million of the Deferred credits and other liabilities balance applies to Progress Energy.
[3]	Includes book value of Non-recourse long-term debt of variable interest entities of $300 million at both September 30, 2013 and December 31, 2012, respectively.

Variable_Interest_Entities_Fai

Variable Interest Entities (Fair Value Assumptions)(Details) (Cinergy Receivables [Member])	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Duke Energy Ohio [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Anticipated credit loss ratio	0.60%	0.70%
Discount rate	1.20%	1.20%
Receivable turnover rate	12.80%	12.70%
Duke Energy Indiana [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Anticipated credit loss ratio	0.30%	0.30%
Discount rate	1.20%	1.20%
Receivable turnover rate	10.30%	10.20%

Variable_Interest_Entities_Rec

Variable Interest Entities (Receivables Sold)(Details) (Cinergy Receivables [Member], USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Duke Energy Ohio [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Receivables sold	$235	$282
Less: retained interests	75	97
Net receivables sold	160	185
Duke Energy Indiana [Member]	'	'
Variable Interest Entity [Line Items]	'	'
Receivables sold	332	289
Less: retained interests	114	116
Net receivables sold	$218	$173

Variable_Interest_Entities_Sal

Variable Interest Entities (Sales and Cash Flows)(Details) (Cinergy Receivables [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Duke Energy Ohio [Member]	'	'	'	'
Variable Interest Entity [Line Items]	'	'	'	'
Receivables sold	$514	$518	$1,664	$1,618
Gain (loss) recognized on sale	-3	-3	-9	-10
Cash proceeds from receivables sold	518	531	1,674	1,651
Return received on retained interests	1	1	4	4
Collection fees received	'	'	1	1
Duke Energy Indiana [Member]	'	'	'	'
Variable Interest Entity [Line Items]	'	'	'	'
Receivables sold	765	711	2,214	2,118
Gain (loss) recognized on sale	-2	-3	-8	-9
Cash proceeds from receivables sold	758	733	2,204	2,130
Return received on retained interests	2	2	5	5
Collection fees received	'	'	$1	$1

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, except Per Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Earnings Per Share [Line Items]	'	'	'	'
Average shares, basic	706	699	706	531
Average shares, diluted	706	699	706	531
EPS, basic	$1.40	$0.84	$2.78	$2.50
EPS, diluted	$1.40	$0.84	$2.78	$2.50
Number of stock options and performance and unvested stock awards excluded from the dilutive securities calculation	'	'	2	1
Income [Member]	'	'	'	'
Earnings Per Share [Line Items]	'	'	'	'
Income from continuing operations attributable to Duke Energy common stockholders, as adjusted for participating securities - basic and diluted	$989	$589	$1,959	$1,326
Average Shares [Member]	'	'	'	'
Earnings Per Share [Line Items]	'	'	'	'
Average shares, basic and diluted	706	699	706	531
EPS [Member]	'	'	'	'
Earnings Per Share [Line Items]	'	'	'	'
EPS, basic and diluted	$1.40	$0.84	$2.78	$2.50

StockBased_Compensation_Schedu

Stock-Based Compensation (Schedule of Stock-Based Compensation Expense) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Pretax stock-based compensation expense	$17	$32	$63	$51
Tax benefit associated with stock-based compensation expense	6	13	24	20
Stock-based compensation costs capitalized	1	0	3	1
Stock Options [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Pretax stock-based compensation expense	'	'	2	2
Restricted Stock Units Awards [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Pretax stock-based compensation expense	10	16	36	30
Performance Awards [Member]	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Pretax stock-based compensation expense	$7	$16	$25	$19

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Contribution to Qualified Pension Plan [Abstract]	'	'	'	'
Contribution to qualified pension plan	'	'	$27	'
Employee Savings Plans [Abstract]	'	'	'	'
Matching contribution percentage	'	'	100.00%	'
Eligible pay percentage	'	'	6.00%	'
Pretax employer matching contributions	30	30	101	77
Fixed-income Assets [Member]	'	'	'	'
Pension Plan Asset Allocation [Abstract]	'	'	'	'
Actual asset allocation	60.00%	'	60.00%	'
Return-seeking Assets [Member]	'	'	'	'
Pension Plan Asset Allocation [Abstract]	'	'	'	'
Actual asset allocation	40.00%	'	40.00%	'
Other Post-Retirement Benefit plans [Member]	'	'	'	'
Remeasurement [Abstract]	'	'	'	'
Plan amendments	'	'	551	'
Duke Energy Carolinas [Member]	'	'	'	'
Employee Savings Plans [Abstract]	'	'	'	'
Pretax employer matching contributions	10	8	34	28
Progress Energy [Member]	'	'	'	'
Contribution to Qualified Pension Plan [Abstract]	'	'	'	'
Contribution to qualified pension plan	'	'	27	'
Employee Savings Plans [Abstract]	'	'	'	'
Pretax employer matching contributions	12	12	34	35
Progress Energy [Member] \| Fixed-income Assets [Member]	'	'	'	'
Pension Plan Asset Allocation [Abstract]	'	'	'	'
Actual asset allocation	55.00%	'	55.00%	'
Progress Energy [Member] \| Return-seeking Assets [Member]	'	'	'	'
Pension Plan Asset Allocation [Abstract]	'	'	'	'
Actual asset allocation	45.00%	'	45.00%	'
Progress Energy [Member] \| Other Post-Retirement Benefit plans [Member]	'	'	'	'
Remeasurement [Abstract]	'	'	'	'
Discount rate	4.70%	'	4.70%	'
Health care cost trend rate assumed for next year	'	'	8.50%	'
Rate to which the cost trend is assumed to decline (the ultimate trend rate)	'	'	5.00%	'
Plan amendments	'	'	551	'
Duke Energy Progress [Member]	'	'	'	'
Employee Savings Plans [Abstract]	'	'	'	'
Pretax employer matching contributions	7	7	19	18
Duke Energy Progress [Member] \| Other Post-Retirement Benefit plans [Member]	'	'	'	'
Remeasurement [Abstract]	'	'	'	'
Plan amendments	'	'	382	'
Duke Energy Florida [Member]	'	'	'	'
Contribution to Qualified Pension Plan [Abstract]	'	'	'	'
Contribution to qualified pension plan	'	'	27	'
Employee Savings Plans [Abstract]	'	'	'	'
Pretax employer matching contributions	4	4	11	11
Duke Energy Florida [Member] \| Other Post-Retirement Benefit plans [Member]	'	'	'	'
Remeasurement [Abstract]	'	'	'	'
Plan amendments	'	'	103	'
Duke Energy Ohio [Member]	'	'	'	'
Employee Savings Plans [Abstract]	'	'	'	'
Pretax employer matching contributions	0	1	2	3
Duke Energy Indiana [Member]	'	'	'	'
Employee Savings Plans [Abstract]	'	'	'	'
Pretax employer matching contributions	$2	$2	$5	$5

Employee_Benefit_Plans_Compone

Employee Benefit Plans (Components of Net Periodic Pension Costs) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	$41		$39		$125		$84
Interest cost on benefit obligation	80		94		240		214
Expected return on plan assets	-137		-142		-411		-330
Amortization of actuarial loss (gain)	61		47		183		96
Amortization of prior service cost (credit)	-2		3		-8		6
Other	2		2		5		4
Net periodic costs	45	[1]	43	[1]	134	[2]	74	[2]
Regulatory asset amortization	3		3		9		10
Non-Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	1		'		2		1
Interest cost on benefit obligation	3		5		10		8
Amortization of actuarial loss (gain)	1		1		4		2
Amortization of prior service cost (credit)	'		'		-1		1
Net periodic costs	5		6		15		12
Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	7		7		21		10
Interest cost on benefit obligation	19		19		55		36
Expected return on plan assets	-4		-4		-11		-12
Amortization of net transition liability	'		3		'		7
Amortization of actuarial loss (gain)	13		8		39		5
Amortization of prior service cost (credit)	-3		-2		-9		-6
Special termination charges	'		9		'		9
Net periodic costs	32	[3]	40	[3]	95	[4]	49	[4]
Regulatory asset amortization	2		3		6		7
Duke Energy Carolinas [Member] \| Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	12		9		37		26
Interest cost on benefit obligation	20		23		60		68
Expected return on plan assets	-37		-36		-111		-109
Amortization of actuarial loss (gain)	15		11		45		34
Amortization of prior service cost (credit)	-2		'		-5		1
Other	1		'		2		1
Net periodic costs	9		7		28		21
Duke Energy Carolinas [Member] \| Non-Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Interest cost on benefit obligation	'		'		1		1
Net periodic costs	'		'		1		1
Duke Energy Carolinas [Member] \| Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	1		1		2		2
Interest cost on benefit obligation	3		4		9		12
Expected return on plan assets	-2		-3		-7		-8
Amortization of net transition liability	'		2		'		5
Amortization of actuarial loss (gain)	'		1		2		2
Amortization of prior service cost (credit)	-2		-2		-6		-4
Special termination charges	'		1		'		1
Net periodic costs	0		4		0		10
Progress Energy [Member] \| Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	15		16		45		47
Interest cost on benefit obligation	29		32		87		95
Expected return on plan assets	-50		-48		-149		-141
Amortization of actuarial loss (gain)	26		24		76		69
Amortization of prior service cost (credit)	-1		2		-3		7
Other	'		1		1		1
Net periodic costs	19		27		57		78
Progress Energy [Member] \| Non-Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	1		'		1		1
Interest cost on benefit obligation	1		2		5		6
Amortization of actuarial loss (gain)	1		1		3		3
Amortization of prior service cost (credit)	'		'		-1		'
Net periodic costs	3		3		8		10
Progress Energy [Member] \| Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	6		5		17		12
Interest cost on benefit obligation	12		11		35		32
Expected return on plan assets	'		'		'		-1
Amortization of net transition liability	'		1		'		3
Amortization of actuarial loss (gain)	13		10		42		25
Amortization of prior service cost (credit)	'		'		-1		'
Special termination charges	'		5		'		5
Net periodic costs	31		32		93		76
Duke Energy Progress [Member] \| Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	6		6		17		19
Interest cost on benefit obligation	13		15		38		43
Expected return on plan assets	-24		-25		-71		-72
Amortization of actuarial loss (gain)	11		9		34		28
Amortization of prior service cost (credit)	-1		2		-1		6
Other	1		1		1		1
Net periodic costs	6		8		18		25
Duke Energy Progress [Member] \| Non-Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	1		'		1		1
Interest cost on benefit obligation	'		1		1		1
Amortization of actuarial loss (gain)	1		'		1		1
Net periodic costs	2		1		3		3
Duke Energy Progress [Member] \| Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	3		2		9		6
Interest cost on benefit obligation	7		6		19		17
Amortization of actuarial loss (gain)	8		6		26		14
Amortization of prior service cost (credit)	'		'		-1		'
Special termination charges	'		2		'		2
Net periodic costs	18		16		53		39
Duke Energy Florida [Member] \| Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	8		8		23		22
Interest cost on benefit obligation	13		14		40		42
Expected return on plan assets	-21		-21		-65		-61
Amortization of actuarial loss (gain)	12		13		37		36
Amortization of prior service cost (credit)	-1		'		-2		'
Net periodic costs	11		14		33		39
Duke Energy Florida [Member] \| Non-Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Interest cost on benefit obligation	'		1		1		2
Amortization of actuarial loss (gain)	1		'		1		'
Net periodic costs	1		1		2		2
Duke Energy Florida [Member] \| Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	2		2		6		5
Interest cost on benefit obligation	5		4		13		13
Expected return on plan assets	'		'		'		-1
Amortization of net transition liability	'		1		'		2
Amortization of actuarial loss (gain)	4		3		12		9
Special termination charges	'		1		'		1
Net periodic costs	11		11		31		29
Duke Energy Ohio [Member] \| Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	1		2		4		5
Interest cost on benefit obligation	5		7		16		23
Expected return on plan assets	-7		-11		-22		-33
Amortization of actuarial loss (gain)	3		2		9		7
Net periodic costs	2	[5]	0	[5]	7	[6]	2	[6]
Regulatory asset amortization	1		2		4		5
Duke Energy Ohio [Member] \| Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	'		1		'		1
Interest cost on benefit obligation	'		1		1		2
Expected return on plan assets	'		-1		'		-1
Amortization of actuarial loss (gain)	'		-1		-1		-2
Net periodic costs	'		0		0	[7]	0	[7]
Regulatory asset amortization	'		'		1		1
Duke Energy Indiana [Member] \| Qualified Pension Plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	2		2		8		7
Interest cost on benefit obligation	7		8		21		23
Expected return on plan assets	-11		-12		-33		-35
Amortization of actuarial loss (gain)	6		3		17		10
Amortization of prior service cost (credit)	'		1		'		2
Other	1		'		1		'
Net periodic costs	5		2		14		7
Duke Energy Indiana [Member] \| Other Post-Retirement Benefit plans [Member]	'		'		'		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'		'		'		'
Service cost	1		1		1		1
Interest cost on benefit obligation	1		1		4		5
Expected return on plan assets	-1		'		-1		-1
Amortization of actuarial loss (gain)	1		'		1		-1
Amortization of prior service cost (credit)	'		'		'		1
Net periodic costs	$2		$2		$5		$5

[1]	Duke Energy amounts exclude $3 million for each of the three months ended September 30, 2013 and 2012, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.
[2]	Duke Energy amounts exclude $9 million and $10 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.
[3]	Duke Energy amounts exclude $2 million and $3 million for the three months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.
[4]	Duke Energy amounts exclude $6 million and $7 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.
[5]	Duke Energy Ohio amounts exclude $1 million and $2 million for the three months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.
[6]	Duke Energy Ohio amounts exclude $4 million and $5 million for the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.
[7]	Duke Energy Ohio amounts exclude $1 million for each of the nine months ended September 30, 2013 and 2012, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energybs merger with Cinergy.

Severance_NarrativeDetails

Severance (Narrative)(Details) (USD $)	1 Months Ended	9 Months Ended	12 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Nov. 30, 2011	Sep. 30, 2013	Dec. 31, 2012	Oct. 31, 2012
	2011 Severance Plan [Member]	Duke Energy Florida [Member]	Duke Energy Florida [Member]	Duke Energy Ohio [Member]
	Employees	Crystal River Unit 3 2013 Severance Plan [Member]	Crystal River Unit 3 2013 Severance Plan [Member]	Duke Energy Ohio Union 2012 Severance Plan [Member]
			Employees	Employees
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Number of employees that accepted the termination benefits	1,100	'	'	75
Number of eligible employees	'	'	600	'
Deferred severance costs	'	$26	'	'

Severance_Expense_Table_Detail

Severance Expense Table (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	$5	$146	$30	$146
Duke Energy Carolinas [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	0	48	7	48
Progress Energy [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	4	66	17	66
Duke Energy Progress [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	3	42	12	42
Duke Energy Florida [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	1	24	5	24
Duke Energy Ohio [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	0	15	2	15
Duke Energy Indiana [Member]	'	'	'	'
Restructuring Cost and Reserve [Line Items]	'	'	'	'
Severance expense	$0	$13	$2	$13

Severance_Rollforward_Details

Severance Rollforward (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	$135
Provision/adjustments	41	[1]
Cash reductions	-114
Balance at September 30, 2013	62
Duke Energy Carolinas [Member]	'
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	12
Provision/adjustments	2
Cash reductions	-12
Balance at September 30, 2013	2
Progress Energy [Member]	'
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	43
Provision/adjustments	45	[1]
Cash reductions	-42
Balance at September 30, 2013	46
Duke Energy Progress [Member]	'
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	23
Provision/adjustments	7
Cash reductions	-17
Balance at September 30, 2013	13
Duke Energy Florida [Member]	'
Restructuring Reserve [Roll Forward]	'
Balance at December 31, 2012	6
Provision/adjustments	30	[1]
Cash reductions	-13
Balance at September 30, 2013	$23

[1]	Provision / Adjustments for Duke Energy, Progress Energy and Duke Energy Florida includes $26 million of severance costs deferred related to Crystal River Unit 3.

Income_Taxes_Effective_Tax_Rat

Income Taxes (Effective Tax Rates) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	31.50%	29.40%	32.60%	29.60%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	$170	$178	$461	$325
State [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Net reduction in deferred tax liability	145	'	145	'
State [Member] \| Current [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Statutory tax rate	'	'	6.90%	'
State [Member] \| January 2014 [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Statutory tax rate	'	'	6.00%	'
State [Member] \| January 2015 [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Statutory tax rate	'	'	5.00%	'
Duke Energy Carolinas [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	37.90%	34.20%	37.50%	35.80%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	46	47	124	125
Progress Energy [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	38.80%	32.80%	38.10%	34.70%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	89	95	230	241
Duke Energy Progress [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	35.70%	31.90%	37.30%	31.60%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	33	33	88	85
Duke Energy Florida [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	40.00%	35.90%	40.00%	36.90%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	56	62	142	156
Duke Energy Ohio [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	42.90%	45.20%	40.40%	38.90%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	26	26	81	79
Duke Energy Indiana [Member]	'	'	'	'
Reconciliation of Income Tax Expense at the U.S. Federal Statutory Tax Rate to the Actual Tax Expense from Continuing Operations [Abstract]	'	'	'	'
Effective tax rate	36.60%	55.10%	37.20%	47.70%
Excise Taxes [Abstract]	'	'	'	'
Excise taxes	$9	$9	$26	$25

Income_Taxes_Other_Disclosures

Income Taxes (Other Disclosures) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	$540
Gross decreases-tax positions in prior periods	-230
Settlements	-66
Total changes	-296
Unrecognized Tax Benefits - September 30	244	[1]
Duke Energy Carolinas [Member]	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	271
Gross decreases-tax positions in prior periods	-96
Settlements	-4
Total changes	-100
Unrecognized Tax Benefits - September 30	171	[1]
Progress Energy [Member]	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	131
Gross decreases-tax positions in prior periods	-85
Total changes	-85
Unrecognized Tax Benefits - September 30	46	[1]
Duke Energy Progress [Member]	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	67
Gross decreases-tax positions in prior periods	-45
Total changes	-45
Unrecognized Tax Benefits - September 30	22	[1]
Duke Energy Florida [Member]	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	44
Gross decreases-tax positions in prior periods	-37
Total changes	-37
Unrecognized Tax Benefits - September 30	7	[1]
Duke Energy Ohio [Member]	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	36
Gross decreases-tax positions in prior periods	-36
Total changes	-36
Unrecognized Tax Benefits - September 30	0	[1]
Duke Energy Indiana [Member]	'
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'
Unrecognized Tax Benefits - January 1	32
Gross decreases-tax positions in prior periods	-31
Total changes	-31
Unrecognized Tax Benefits - September 30	$1	[1]

[1]	The Duke Energy Registrants do not anticipate a significant increase or decrease in unrecognized tax benefits in the next twelve months.

Related_Party_Transactions_Oth

Related Party Transactions (Other Revenue and Expense) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Duke Energy Carolinas [Member] \| Corporate Governance And Shared Service Expenses [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	$236	[1]	$309	[1]	$714	[1]	$798	[1]
Duke Energy Carolinas [Member] \| Indemnification Coverages [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	5	[2]	5	[2]	16	[2]	16	[2]
Duke Energy Carolinas [Member] \| Joint Dispatch Agreement [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, other revenues from transactions with related party	24	[3]	8	[3]	101	[3]	8	[3]
Related party transaction, expenses from transactions with related party	39	[3]	37	[3]	71	[3]	37	[3]
Progress Energy [Member] \| Corporate Governance And Shared Service Expenses [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, other revenues from transactions with related party	24	[4]	30	[4]	74	[4]	30	[4]
Related party transaction, expenses from transactions with related party	54	[1]	31	[1]	327	[1]	31	[1]
Progress Energy [Member] \| Indemnification Coverages [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	9	[2]	7	[2]	26	[2]	7	[2]
Progress Energy [Member] \| Joint Dispatch Agreement [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, other revenues from transactions with related party	39	[3]	37	[3]	71	[3]	37	[3]
Related party transaction, expenses from transactions with related party	24	[3]	8	[3]	101	[3]	8	[3]
Duke Energy Progress [Member] \| Corporate Governance And Shared Service Expenses [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	33	[1]	72	[1]	195	[1]	183	[1]
Duke Energy Progress [Member] \| Indemnification Coverages [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	5	[2]	3	[2]	15	[2]	3	[2]
Duke Energy Progress [Member] \| Joint Dispatch Agreement [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, other revenues from transactions with related party	39	[3]	37	[3]	71	[3]	37	[3]
Related party transaction, expenses from transactions with related party	24	[3]	8	[3]	101	[3]	8	[3]
Duke Energy Florida [Member] \| Corporate Governance And Shared Service Expenses [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	20	[1]	52	[1]	131	[1]	136	[1]
Duke Energy Florida [Member] \| Indemnification Coverages [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	4	[2]	4	[2]	11	[2]	4	[2]
Duke Energy Ohio [Member] \| Corporate Governance And Shared Service Expenses [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	89	[1]	103	[1]	261	[1]	279	[1]
Duke Energy Ohio [Member] \| Indemnification Coverages [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	3	[2]	4	[2]	11	[2]	11	[2]
Duke Energy Ohio [Member] \| MarkTo Market Of Commodity Contracts And Sales Of Power [Member] \| DECAM [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, other revenues from transactions with related party	'		'		'		31
Related party transaction, expenses from transactions with related party	'		'		7		'
Duke Energy Indiana [Member] \| Corporate Governance And Shared Service Expenses [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	113	[1]	118	[1]	313	[1]	317	[1]
Duke Energy Indiana [Member] \| Indemnification Coverages [Member]	'		'		'		'
Related Party Transaction [Line Items]	'		'		'		'
Related party transaction, expenses from transactions with related party	$5	[2]	$2	[2]	$10	[2]	$6	[2]

[1]	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates. These entities are consolidated affiliates of Duke Energy and Progress Energy. Corporate governance and other shared services costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
[2]	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energybs wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.
[3]	Effective with the consummation of the merger between Duke Energy and Progress Energy, Duke Energy Carolinas and Duke Energy Progress began to participate in a JDA. The JDA allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.
[4]	Progress Energy charges a proportionate share of corporate governance and other costs to unconsolidated affiliates that are consolidated affiliates of Duke Energy. Corporate governance and other shared costs are primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges are recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income.

Related_Party_Transactions_Nar

Related Party Transactions (Narrative) (Details) (USD $)	0 Months Ended	9 Months Ended
In Millions, unless otherwise specified	Jan. 12, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Related Party Transaction [Line Items]	'	'	'	'
Debt instrument, face amount	'	$3,771	'	'
Duke Energy Carolinas [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Intercompany loan receivable	'	595	'	382
Dividends to parent	'	-500	-250	'
Progress Energy [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Intercompany loan receivable	'	103	'	0
Intercompany loan payable	'	1,195	'	455
Duke Energy Progress [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Dividends to parent	'	0	-310	'
Intercompany loan payable	'	581	'	364
Debt instrument, face amount	'	548	'	'
Duke Energy Florida [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Intercompany loan receivable	'	30	'	207
Dividends to parent	'	-225	-170	'
Duke Energy Ohio [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Intercompany loan receivable	'	46	'	1
Transfer of Vermillion Generating Station	28	'	28	'
Intercompany loan payable	'	69	'	245
Debt instrument, face amount	'	450	'	'
Duke Energy Ohio [Member] \| DECAM [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Intercompany loan receivable	'	'	46	'
Intercompany loan payable	'	'	'	79
Duke Energy Indiana [Member]	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
Intercompany loan receivable	'	69	'	0
Dividends to parent	'	-125	0	'
Transfer of Vermillion Generating Station	26	0	26	'
Intercompany loan payable	'	0	'	81
Debt instrument, face amount	'	$500	'	'