Duke Energy Carolinas 10-K28 Feb 142013 FY Annual reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
Document and Entity Information (USD $)	Dec. 31, 2013	Feb. 25, 2014	Jun. 30, 2013
Document Information [Line Items]	'	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Entity Registrant Name	'Duke Energy Corporation	'	'
Entity Central Index Key	'0001326160	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Common Stock, Shares Outstanding	'	706,455,305	'
Entity Public Float	'	'	$47,550,155,353
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Duke Energy Carolinas [Member]	'	'	'
Document Information [Line Items]	'	'	'
Entity Registrant Name	'Duke Energy Carolinas, LLC	'	'
Entity Central Index Key	'0000030371	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Progress Energy [Member]	'	'	'
Document Information [Line Items]	'	'	'
Entity Registrant Name	'Progress Energy, Inc.	'	'
Entity Central Index Key	'0001094093	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Duke Energy Progress [Member]	'	'	'
Document Information [Line Items]	'	'	'
Entity Registrant Name	'Duke Energy Progress, Inc.	'	'
Entity Central Index Key	'0000017797	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Duke Energy Florida [Member]	'	'	'
Document Information [Line Items]	'	'	'
Entity Registrant Name	'Duke Energy Florida, Inc.	'	'
Entity Central Index Key	'0000037637	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Duke Energy Ohio [Member]	'	'	'
Document Information [Line Items]	'	'	'
Entity Registrant Name	'Duke Energy Ohio, Inc.	'	'
Entity Central Index Key	'0000020290	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Duke Energy Indiana [Member]	'	'	'
Document Information [Line Items]	'	'	'
Entity Registrant Name	'Duke Energy Indiana, Inc.	'	'
Entity Central Index Key	'0000081020	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Well-known Seasoned Issuer	'No	'	'

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2011
Operating Revenues [Abstract]	'	'		'
Regulated electric	$20,439	$15,621		$10,589
Non-regulated electric, natural gas, and other	3,648	3,534		3,383
Regulated natural gas	511	469		557
Total operating revenues	24,598	19,624		14,529
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	7,108	5,582		3,309
Fuel used in electric generation and purchased power - non-regulated	1,822	1,722		1,488
Cost of natural gas and coal sold	254	264		348
Operation, maintenance and other	5,910	5,006		3,770
Depreciation and amortization	2,808	2,289		1,806
Property and other taxes	1,299	985		704
Impairment charges	399	666		335
Total operating expenses	19,600	16,514		11,760
Gains (Losses) on Sales of Other Assets and Other, net	-16	16		8
Operating Income (Loss)	4,982	3,126		2,777
Other Income and Expenses [Abstract]	'	'		'
Equity in earnings of unconsolidated affiliates	122	148		160
Impairments and gains on sales of unconsolidated affiliates	100	22		11
Other income and expenses, net	262	397		376
Total other income and expenses	484	567		547
Interest Expense	1,546	1,242		859
Income (Loss) From Continuing Operations Before Income Taxes	3,920	2,451		2,465
Income Tax Expense or Benefit from Continuing Operations	1,261	705		752
Income (Loss) from Continuing Operations	2,659	1,746		1,713
Income (Loss) From Discontinued Operations, net of tax	17	36		1
Net Income (Loss)	2,676	1,782		1,714
Less: Net Income (Loss) Attributable to Noncontrolling Interests	11	14		8
Net Income (Loss) Attributable to Duke Energy	2,665	1,768		1,706
Net Income (Loss) Available to Parent	'	1,780	[1]	'
Net Income (Loss)	2,676	1,782		1,714
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Pension and OPEB adjustments	38	19		-49
Net unrealized gain (loss) on cash flow hedges	59	-28		-57
Reclassification into earnings from cash flow hedges	-1	1		-4
Unrealized gain (loss) on investments in available for sale securities	-4	14		12
Other comprehensive income (loss), net of tax	-99	-76		-243
Comprehensive Income (Loss)	2,577	1,706		1,471
Less: Comprehensive Income Attributable to Noncontrolling Interests	5	10		1
Comprehensive income (loss)	2,572	1,696		1,470
Income From Continuing Operations Attributable To Parent Common Shareholders [Abstract]	'	'		'
Basic	$3.74	$3.01		$3.83
Diluted	$3.74	$3.01		$3.83
Income (loss) from discontinued operations attributable To Duke Energy Corporation common shareholders [Abstract]	'	'		'
Basic	$0.03	$0.06		'
Diluted	$0.02	$0.06		'
Net income attributable to Duke Energy Corporation common shareholders [Abstract]	'	'		'
Basic	$3.77	$3.07		$3.83
Diluted	$3.76	$3.07		$3.83
Dividends declared per share	$3.09	$3.03		$2.97
Weighted-average shares outstanding [Abstract]	'	'		'
Basic	706	574		444
Diluted	706	575		444
Duke Energy Carolinas [Member]	'	'		'
Operating Revenues [Abstract]	'	'		'
Total operating revenues	6,954	6,665		6,493
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	1,982	1,864		1,944
Operation, maintenance and other	1,868	1,979		1,904
Depreciation and amortization	921	921		814
Property and other taxes	374	365		340
Impairment charges	'	31		12
Total operating expenses	5,145	5,160		5,014
Gains (Losses) on Sales of Other Assets and Other, net	'	12		1
Operating Income (Loss)	1,809	1,517		1,480
Other Income and Expenses [Abstract]	'	'		'
Other income and expenses, net	120	185		186
Interest Expense	359	384		360
Income (Loss) From Continuing Operations Before Income Taxes	1,570	1,318		1,306
Income Tax Expense or Benefit from Continuing Operations	594	453		472
Net Income (Loss)	976	865		834
Net Income (Loss)	976	865		834
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Reclassification into earnings from cash flow hedges	1	2		3
Unrealized gain (loss) on investments in available for sale securities	'	1		'
Other comprehensive income (loss), net of tax	1	3		3
Comprehensive income (loss)	977	868		837
Progress Energy [Member]	'	'		'
Operating Revenues [Abstract]	'	'		'
Total operating revenues	9,533	9,405		8,948
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	3,851	4,304		4,043
Operation, maintenance and other	2,247	2,445		2,060
Depreciation and amortization	883	747		701
Property and other taxes	557	570		562
Impairment charges	380	200		3
Total operating expenses	7,918	8,266		7,369
Gains (Losses) on Sales of Other Assets and Other, net	3	-2		4
Operating Income (Loss)	1,618	1,137		1,583
Other Income and Expenses [Abstract]	'	'		'
Other income and expenses, net	94	130		52
Interest Expense	680	740		725
Income (Loss) From Continuing Operations Before Income Taxes	1,032	527		910
Income Tax Expense or Benefit from Continuing Operations	373	172		323
Income (Loss) from Continuing Operations	659	355		587
Income (Loss) From Discontinued Operations, net of tax	16	52		-5
Net Income (Loss)	675	407		582
Less: Net Income (Loss) Attributable to Noncontrolling Interests	3	7		7
Net Income (Loss) Attributable to Duke Energy	672	400		575
Net Income (Loss)	675	407		582
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Pension and OPEB adjustments	9	-2		39	[2]
Net unrealized gain (loss) on cash flow hedges	0	-5		-87	[3]
Reclassification into earnings from cash flow hedges	-1	8	[4]	8	[4]
Reclassification of cash flow hedges to regulatory assets	0	97	[5]	0
Other comprehensive income (loss), net of tax	8	98		-40
Comprehensive Income (Loss)	683	505		542
Duke Energy Progress [Member]	'	'		'
Operating Revenues [Abstract]	'	'		'
Total operating revenues	4,992	4,706		4,547
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	1,925	1,895		1,755
Operation, maintenance and other	1,357	1,494		1,191
Depreciation and amortization	534	535		514
Property and other taxes	223	219		211
Impairment charges	22	54		3
Total operating expenses	4,061	4,197		3,674
Gains (Losses) on Sales of Other Assets and Other, net	1	1		3
Operating Income (Loss)	932	510		876
Other Income and Expenses [Abstract]	'	'		'
Other income and expenses, net	57	79		80
Interest Expense	201	207		184
Income (Loss) From Continuing Operations Before Income Taxes	788	382		772
Income Tax Expense or Benefit from Continuing Operations	288	110		256
Net Income (Loss)	500	272		516
Less: Preferred Stock Dividend Requirement	0	3		3
Net Income (Loss) Available to Parent	500	269		513
Net Income (Loss)	500	272		516
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Net unrealized gain (loss) on cash flow hedges	0	-4		-43	[6]
Reclassification into earnings from cash flow hedges	0	4		5
Reclassification of cash flow hedges to regulatory assets	0	71	[7]	0
Other comprehensive income (loss), net of tax	0	71		-38
Comprehensive income (loss)	500	343		478
Duke Energy Florida [Member]	'	'		'
Operating Revenues [Abstract]	'	'		'
Total operating revenues	4,527	4,689		4,392
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	1,927	2,409		2,288
Operation, maintenance and other	898	969		883
Depreciation and amortization	330	192		169
Property and other taxes	327	346		351
Impairment charges	358	146		0
Total operating expenses	3,840	4,062		3,691
Gains (Losses) on Sales of Other Assets and Other, net	1	2		2
Operating Income (Loss)	688	629		703
Other Income and Expenses [Abstract]	'	'		'
Other income and expenses, net	30	39		30
Interest Expense	180	255		239
Income (Loss) From Continuing Operations Before Income Taxes	538	413		494
Income Tax Expense or Benefit from Continuing Operations	213	147		180
Net Income (Loss)	325	266		314
Less: Preferred Stock Dividend Requirement	0	2		2
Net Income (Loss) Available to Parent	325	264		312
Net Income (Loss)	325	266		314
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Net unrealized gain (loss) on cash flow hedges	-1	0		-23	[8]
Reclassification into earnings from cash flow hedges	0	1		0
Reclassification of cash flow hedges to regulatory assets	0	26	[9]	0
Other comprehensive income (loss), net of tax	-1	27		-23
Comprehensive income (loss)	324	293		291
Duke Energy Ohio [Member]	'	'		'
Operating Revenues [Abstract]	'	'		'
Regulated electric	1,368	1,386		1,518
Non-regulated electric, natural gas, and other	1,364	1,295		1,105
Regulated natural gas	513	471		558
Total operating revenues	3,245	3,152		3,181
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	429	475		380
Fuel used in electric generation and purchased power - non-regulated	1,020	832		653
Cost of natural gas and coal sold	152	142		209
Operation, maintenance and other	774	797		885
Depreciation and amortization	354	338		335
Property and other taxes	265	224		260
Impairment charges	5	2		89
Total operating expenses	2,999	2,810		2,811
Gains (Losses) on Sales of Other Assets and Other, net	5	7		5
Operating Income (Loss)	251	349		375
Other Income and Expenses [Abstract]	'	'		'
Other income and expenses, net	4	13		19
Interest Expense	78	89		104
Income (Loss) From Continuing Operations Before Income Taxes	177	273		290
Income Tax Expense or Benefit from Continuing Operations	75	98		96
Net Income (Loss)	102	175		194
Net Income (Loss)	102	175		194
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Pension and OPEB adjustments	1	27	[10]	-6
Other comprehensive income (loss), net of tax	1	27		-6
Comprehensive income (loss)	103	202		188
Duke Energy Indiana [Member]	'	'		'
Operating Revenues [Abstract]	'	'		'
Total operating revenues	2,926	2,717		2,622
Operating Expenses [Abstract]	'	'		'
Fuel used in electric generation and purchased power - regulated	1,131	1,088		986
Operation, maintenance and other	649	655		647
Depreciation and amortization	342	389		391
Property and other taxes	71	81		82
Impairment charges	'	579		234
Total operating expenses	2,193	2,792		2,340
Operating Income (Loss)	733	-75		282
Other Income and Expenses [Abstract]	'	'		'
Other income and expenses, net	18	90		97
Interest Expense	170	138		137
Income (Loss) From Continuing Operations Before Income Taxes	581	-123		242
Income Tax Expense or Benefit from Continuing Operations	223	-73		74
Net Income (Loss)	358	-50		168
Net Income (Loss)	358	-50		168
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'		'
Reclassification into earnings from cash flow hedges	-2	-2		-1
Other comprehensive income (loss), net of tax	-2	-2		-1
Comprehensive income (loss)	$356	($52)		$167

[1]	For the year ended December 31, 2012, consolidated net income of $1,782 million includes $2 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]	Net of $27 million tax expense in 2011.
[3]	Net of $56 million tax benefit in 2011.
[4]	Net of $6 million tax expense in 2012 and $5 million tax expense in 2011.
[5]	Net of $62 million tax expense in 2012.
[6]	Net of $28 million tax benefit in 2011.
[7]	Net of $46 million tax expense in 2012.
[8]	Net of $15 million tax benefit in 2011.
[9]	Net of $16 million tax expense in 2012.
[10]	Net of $8 million tax expense in 2012.

Consolidated_Statement_of_Oper

Consolidated Statement of Operations (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Pension and OPEB adjustments to AOCI, tax	$9	($23)
Net unrealized gains (losses) on cash flow hedges, tax	6	-31
Progress Energy [Member]	'	'
Pension and OPEB adjustments to AOCI, tax	'	27
Net unrealized gains (losses) on cash flow hedges, tax	'	-56
Reclassification into earnings from cash flow hedges, tax	6	5
Reclassification of cash flow hedges to regulatory assets, tax	62	'
Duke Energy Progress [Member]	'	'
Net unrealized gains (losses) on cash flow hedges, tax	'	-28
Reclassification of cash flow hedges to regulatory assets, tax	46	'
Duke Energy Florida [Member]	'	'
Net unrealized gains (losses) on cash flow hedges, tax	'	-15
Reclassification of cash flow hedges to regulatory assets, tax	16	'
Duke Energy Ohio [Member]	'	'
Pension and OPEB adjustments to AOCI, tax	($8)	'

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Comprehensive Income [Abstract]	'	'	'
Net income (loss)	$2,676	$1,782	$1,714
Other Comprehensive Income(Loss), Net of Tax [Abstract]	'	'	'
Foreign currency translation adjustments	-197	-75	-149
Pension and OPEB adjustments	38	19	-49
Net unrealized gain (loss) on cash flow hedges	59	-28	-57
Reclassification into earnings from cash flow hedges	1	-1	4
Unrealized gain (loss) on investments in available for sale securities	-4	14	12
Reclassification into earnings from available for sale securities	4	-5	-4
Other Comprehensive Income (Loss), Net of Tax	-99	-76	-243
Comprehensive Income	2,577	1,706	1,471
Less: Comprehensive Income Attributable to Noncontrolling Interests	5	10	1
Comprehensive Income Attributable to Duke Energy Corporation	$2,572	$1,696	$1,470

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthethical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension and OPEB adjustments to AOCI, tax	$17	$9	($23)
Net unrealized gains (losses) on cash flow hedges, tax	$20	$6	($31)

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Current Assets [Abstract]	'		'
Cash and cash equivalents	$1,501		$1,424
Short Term Investments	44		333
Receivables (net of allowance for doubtful accounts)	1,286		1,516
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	1,719		1,201
Inventory	3,250		3,223
Regulatory assets, current	895		737
Other	1,821		1,688
Total current assets	10,516		10,122
Investments and Other Assets [Abstract]	'		'
Investments in equity method unconsolidated affiliates	390		483
Nuclear decommissioning trust funds	5,132		4,242
Goodwill	16,340		16,365
Other	3,539		2,904
Total investments and other assets	25,401		23,994
Property, Plant and Equipment [Abstract]	'		'
Cost	103,115	[1],[2]	100,391	[3],[4]
Accumulated depreciation and amortization	-33,625		-31,969
Generation facilities to be retired, net	0		136
Net property, plant and equipment	69,490		68,558
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	9,191		11,004
Other	181		178
Total regulatory assets and deferred debits	9,372		11,182
Total Assets	114,779		113,856
Current Liabilities [Abstract]	'		'
Accounts payable	2,391		2,444
Notes payable and commercial paper	839		1,057
Taxes accrued	551		459
Interest accrued	440		448
Current maturities of long-term debt	2,104		3,110
Regulatory liabilities, current	316		156
Other	2,003		2,355
Total current liabilities	8,644		10,029
Long-term debt	38,152		36,351
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	12,097		10,490
Investment tax credits	442		458
Accrued pension and other post-retirement benefit costs	1,322		2,520
Asset retirement obligations	4,950		5,169
Regulatory liabilities - noncurrent	5,949		5,584
Other	1,815		2,221
Total deferred credits and other liabilities	26,575		26,442
Commitments and Contingencies	'		'
Preferred Stock of Subsidiaries	0		93
Equity [Abstract]	'		'
Common stock	1		1
Additional paid-in capital	39,365		39,279
Retained earnings	2,363		1,889
Accumulated other comprehensive (loss) income	-399		-306
Total Common Shareholders' Equity	41,330		40,863
Noncontrolling interests	78		78
Total equity	41,408		40,941
Total Liabilities and Equity	114,779		113,856
Duke Energy Carolinas [Member]	'		'
Current Assets [Abstract]	'		'
Cash and cash equivalents	23		19
Receivables (net of allowance for doubtful accounts)	186		188
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	673		637
Receivables from affiliated companies	75		3
Notes receivable from affiliated companies	222		382
Inventory	1,065		1,062
Regulatory assets, current	295		221
Other	309		218
Total current assets	2,848		2,730
Investments and Other Assets [Abstract]	'		'
Nuclear decommissioning trust funds	2,840		2,354
Other	1,000		934
Total investments and other assets	3,840		3,288
Property, Plant and Equipment [Abstract]	'		'
Cost	34,906	[1]	34,190	[3]
Accumulated depreciation and amortization	-11,894		-11,437
Generation facilities to be retired, net	0		73
Net property, plant and equipment	23,012		22,826
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	1,527		1,727
Other	46		71
Total regulatory assets and deferred debits	1,573		1,798
Total Assets	31,273		30,642
Current Liabilities [Abstract]	'		'
Accounts payable	701		599
Accounts payable to affiliated companies	161		128
Taxes accrued	147		114
Interest accrued	97		96
Current maturities of long-term debt	47		406
Regulatory liabilities, current	65		78
Other	393		412
Total current liabilities	1,611		1,833
Long-term debt	8,089		8,035
Long-term debt payable to affiliated companies	300		300
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	5,706		5,181
Investment tax credits	210		215
Accrued pension and other post-retirement benefit costs	161		221
Asset retirement obligations	1,594		1,959
Regulatory liabilities - noncurrent	2,576		2,102
Other	676		924
Total deferred credits and other liabilities	10,923		10,602
Commitments and Contingencies	'		'
Equity [Abstract]	'		'
Member's equity	10,365		9,888
Accumulated other comprehensive (loss) income	-15		-16
Total Member's Equity	10,350		9,872
Total Liabilities and Equity	31,273		30,642
Progress Energy [Member]	'		'
Current Assets [Abstract]	'		'
Cash and cash equivalents	58		231
Receivables (net of allowance for doubtful accounts)	528		790
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	417		'
Receivables from affiliated companies	4		15
Notes receivable from affiliated companies	75		0
Inventory	1,424		1,441
Regulatory assets, current	353		256
Other	726		510
Total current assets	3,585		3,243
Investments and Other Assets [Abstract]	'		'
Nuclear decommissioning trust funds	2,292		1,888
Goodwill	3,655		3,655
Other	804		530
Total investments and other assets	6,751		6,073
Property, Plant and Equipment [Abstract]	'		'
Cost	36,480	[1]	35,146	[3]
Accumulated depreciation and amortization	-13,098		-12,512
Generation facilities to be retired, net	0		63
Net property, plant and equipment	23,382		22,697
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	4,155		5,292
Other	96		100
Total regulatory assets and deferred debits	4,251		5,392
Total Assets	37,969		37,405
Current Liabilities [Abstract]	'		'
Accounts payable	836		1,066
Accounts payable to affiliated companies	123		30
Notes payable to affiliated companies	1,213		455
Taxes accrued	105		83
Interest accrued	181		192
Current maturities of long-term debt	485		843
Regulatory liabilities, current	207		28
Other	896		1,090
Total current liabilities	4,046		3,787
Long-term debt	13,630		13,311
Long-term debt payable to affiliated companies	0		274
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	3,283		2,558
Accrued pension and other post-retirement benefit costs	765		1,608
Asset retirement obligations	2,562		2,413
Regulatory liabilities - noncurrent	2,292		2,469
Other	527		707
Total deferred credits and other liabilities	9,429		9,755
Commitments and Contingencies	'		'
Preferred Stock of Subsidiaries	0		93
Equity [Abstract]	'		'
Common stock	0		0
Additional paid-in capital	7,467		7,465
Retained earnings	3,452		2,783
Accumulated other comprehensive (loss) income	-59		-67
Total Common Shareholders' Equity	10,860		10,181
Noncontrolling interests	4		4
Total equity	10,864		10,185
Total Liabilities and Equity	37,969		37,405
Duke Energy Progress [Member]	'		'
Current Assets [Abstract]	'		'
Cash and cash equivalents	21		18
Receivables (net of allowance for doubtful accounts)	145		458
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	417		0
Receivables from affiliated companies	2		5
Inventory	853		828
Regulatory assets, current	127		77
Other	296		236
Total current assets	1,861		1,622
Investments and Other Assets [Abstract]	'		'
Nuclear decommissioning trust funds	1,539		1,259
Other	443		251
Total investments and other assets	1,982		1,510
Property, Plant and Equipment [Abstract]	'		'
Cost	22,273	[1]	21,184	[3]
Accumulated depreciation and amortization	-8,623		-8,185
Generation facilities to be retired, net	0		63
Net property, plant and equipment	13,650		13,062
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	1,384		1,845
Other	32		29
Total regulatory assets and deferred debits	1,416		1,874
Total Assets	18,909		18,068
Current Liabilities [Abstract]	'		'
Accounts payable	420		542
Accounts payable to affiliated companies	103		76
Notes payable to affiliated companies	462		364
Taxes accrued	37		23
Interest accrued	70		69
Current maturities of long-term debt	174		407
Regulatory liabilities, current	63		10
Other	392		507
Total current liabilities	1,721		1,998
Long-term debt	5,061		4,433
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	2,557		2,162
Accrued pension and other post-retirement benefit costs	321		715
Asset retirement obligations	1,729		1,649
Regulatory liabilities - noncurrent	1,673		1,538
Other	222		387
Total deferred credits and other liabilities	6,502		6,451
Commitments and Contingencies	'		'
Preferred stock	0		59
Equity [Abstract]	'		'
Common stock	2,159		2,159
Retained earnings	3,466		2,968
Total equity	5,625		5,127
Total Liabilities and Equity	18,909		18,068
Duke Energy Florida [Member]	'		'
Current Assets [Abstract]	'		'
Cash and cash equivalents	16		131
Receivables (net of allowance for doubtful accounts)	375		318
Receivables from affiliated companies	3		20
Notes receivable from affiliated companies	0		207
Inventory	571		613
Regulatory assets, current	221		179
Other	182		172
Total current assets	1,368		1,640
Investments and Other Assets [Abstract]	'		'
Nuclear decommissioning trust funds	753		629
Other	252		182
Total investments and other assets	1,005		811
Property, Plant and Equipment [Abstract]	'		'
Cost	13,863	[1]	13,432	[3]
Accumulated depreciation and amortization	-4,252		-4,072
Net property, plant and equipment	9,611		9,360
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	2,729		3,321
Other	44		48
Total regulatory assets and deferred debits	2,773		3,369
Total Assets	14,757		15,180
Current Liabilities [Abstract]	'		'
Accounts payable	333		412
Accounts payable to affiliated companies	38		44
Notes payable to affiliated companies	181		0
Taxes accrued	66		48
Interest accrued	46		55
Current maturities of long-term debt	11		435
Regulatory liabilities, current	144		18
Other	445		516
Total current liabilities	1,264		1,528
Long-term debt	4,875		4,885
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	1,829		1,518
Accrued pension and other post-retirement benefit costs	286		610
Asset retirement obligations	833		764
Regulatory liabilities - noncurrent	618		787
Other	255		255
Total deferred credits and other liabilities	3,821		3,934
Commitments and Contingencies	'		'
Preferred stock	0		34
Equity [Abstract]	'		'
Common stock	1,762		1,762
Retained earnings	3,036		3,037
Accumulated other comprehensive (loss) income	-1		0
Total equity	4,797		4,799
Total Liabilities and Equity	14,757		15,180
Duke Energy Ohio [Member]	'		'
Current Assets [Abstract]	'		'
Cash and cash equivalents	36		31
Receivables (net of allowance for doubtful accounts)	121		108
Receivables from affiliated companies	121		82
Notes receivable from affiliated companies	57		1
Inventory	229		227
Regulatory assets, current	57		46
Other	270		221
Total current assets	891		716
Investments and Other Assets [Abstract]	'		'
Goodwill	920		921
Other	232		204
Total investments and other assets	1,152		1,125
Property, Plant and Equipment [Abstract]	'		'
Cost	11,143	[1]	10,824	[3]
Accumulated depreciation and amortization	-2,908		-2,698
Net property, plant and equipment	8,235		8,126
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	471		579
Other	14		14
Total regulatory assets and deferred debits	485		593
Total Assets	10,763		10,560
Current Liabilities [Abstract]	'		'
Accounts payable	319		318
Accounts payable to affiliated companies	77		62
Notes payable to affiliated companies	43		245
Taxes accrued	167		159
Interest accrued	17		14
Current maturities of long-term debt	47		261
Regulatory liabilities, current	27		39
Other	110		87
Total current liabilities	807		1,185
Long-term debt	2,141		1,736
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	2,012		1,853
Investment tax credits	0		0
Accrued pension and other post-retirement benefit costs	58		157
Asset retirement obligations	28		28
Regulatory liabilities - noncurrent	262		254
Other	186		181
Total deferred credits and other liabilities	2,546		2,473
Commitments and Contingencies	'		'
Equity [Abstract]	'		'
Common stock	762		762
Additional paid-in capital	4,882		4,882
Retained earnings	-375		-477
Accumulated other comprehensive (loss) income	0		-1
Total equity	5,269		5,166
Total Liabilities and Equity	10,763		10,560
Duke Energy Indiana [Member]	'		'
Current Assets [Abstract]	'		'
Cash and cash equivalents	15		36
Receivables (net of allowance for doubtful accounts)	22		33
Receivables from affiliated companies	151		104
Notes receivable from affiliated companies	96		'
Inventory	434		380
Regulatory assets, current	118		126
Other	125		12
Total current assets	961		691
Investments and Other Assets [Abstract]	'		'
Other	269		163
Total investments and other assets	269		163
Property, Plant and Equipment [Abstract]	'		'
Cost	12,489	[1]	12,012	[3]
Accumulated depreciation and amortization	-3,913		-3,692
Net property, plant and equipment	8,576		8,320
Regulatory Assets and Deferred Debits [Abstract]	'		'
Regulatory assets, noncurrent	717		810
Other	25		24
Total regulatory assets and deferred debits	742		834
Total Assets	10,548		10,008
Current Liabilities [Abstract]	'		'
Accounts payable	206		173
Accounts payable to affiliated companies	56		60
Notes payable to affiliated companies	0		81
Taxes accrued	57		61
Interest accrued	56		53
Current maturities of long-term debt	5		405
Regulatory liabilities, current	16		11
Other	88		154
Total current liabilities	484		998
Long-term debt	3,641		3,147
Long-term debt payable to affiliated companies	150		150
Deferred Credits and Other Liabilities [Abstract]	'		'
Deferred income taxes	1,171		853
Investment tax credits	140		142
Accrued pension and other post-retirement benefit costs	163		186
Asset retirement obligations	30		37
Regulatory liabilities - noncurrent	782		741
Other	48		46
Total deferred credits and other liabilities	2,334		2,005
Commitments and Contingencies	'		'
Equity [Abstract]	'		'
Common stock	1		1
Additional paid-in capital	1,384		1,384
Retained earnings	2,551		2,318
Accumulated other comprehensive (loss) income	3		5
Total equity	3,939		3,708
Total Liabilities and Equity	$10,548		$10,008

[1]	Includes capitalized leases of $1,606 million, $53 million, $328 million, $148 million, $180 million, $96 million, and $30 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $60 million, an insignificant amount and $57 million, respectively, of accumulated amortization of capitalized leases.
[2]	Includes gross property, plant and equipment cost of consolidated VIEs of $1,678 million and accumulated depreciation of consolidated VIEs of $175 million at Duke Energy.
[3]	Includes capitalized leases of $1,844 million, $53 million, $339 million, $150 million, $189 million, $86 million, and $28 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $49 million, an insignificant amount and $48 million, respectively, of accumulated amortization of capitalized leases.
[4]	Includes gross property, plant and equipment cost of consolidated VIEs of $1,558 million and accumulated depreciation of consolidated VIEs of $103 million at Duke Energy.

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Progress Energy [Member]	Progress Energy [Member]	Duke Energy Progress [Member]	Duke Energy Progress [Member]	Duke Energy Florida [Member]	Duke Energy Florida [Member]	Duke Energy Ohio [Member]	Duke Energy Ohio [Member]	Duke Energy Indiana [Member]	Duke Energy Indiana [Member]
Receivables, allowance for doubtful accounts	$30	$34	$14	$16	$10	$9	$4	$7	$2	$2	$1	$1
Restricted receivables, allowance for doubtful accounts	$43	$44	'	'	'	'	'	'	'	'	'	'
Common stock, par value	$0.00	'	$0.01	'	'	'	'	'	$8.50	$8.50	'	'
Common stock, shares authorized	2,000,000,000	2,000,000,000	100	100	200,000,000	200,000,000	60,000,000	60,000,000	120,000,000	120,000,000	60,000,000	60,000,000
Common stock, shares outstanding	706,000,000	704,000,000	100	100	160,000,000	160,000,000	100	100	89,663,086	89,663,086	59,913,701	59,913,701

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	$2,676	$1,782	$1,714
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	3,229	2,652	2,026
Equity component of AFUDC	-157	-300	-260
Severance expense	'	92	'
FERC mitigation costs	'	117	'
Community support and charitable contributions and other	34	92	'
(Gains) losses on sales of other assets	-79	-44	-19
Impairment of other long-lived assets	400	586	335
Deferred income taxes	1,264	584	602
Equity in earnings of unconsolidated affiliates	-122	-148	-160
Voluntary opportunity cost deferral	'	-101	'
Accrued pension and other post-retirement benefit costs	307	239	104
Contributions to qualified pension plans	-250	-304	-200
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	1	60	-48
Receivables	-281	39	2
Inventory	-31	-258	-247
Other current assets	-35	140	185
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	73	131	41
Taxes accrued	77	-142	27
Other current liabilities	24	295	-254
Other assets	-384	-129	12
Other liabilities	-364	-139	-188
Net cash provided by (used in) operating activities	6,382	5,244	3,672
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-5,526	-5,501	-4,363
Investment expenditures	-81	-6	-50
Acquisitions	'	-451	-51
Cash acquired from acquisition	'	71	'
Purchases of available-for-sale securities	-6,142	-4,719	-3,194
Proceeds from sales and maturities of available-for-sale securities	6,315	4,537	3,063
Net proceeds from the sales of other assets, and sales of and collections on notes receivable	277	212	118
Change in restricted cash	167	-414	22
Other	12	74	21
Net cash (used in) provided by investing activities	-4,978	-6,197	-4,434
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	3,601	4,170	2,570
Proceeds from the issuance of common stock related to employee benefit plans	9	23	67
Payments for the redemption of long-term debt	-2,761	-2,498	-278
Payments for the redemption of preferred stock	-96	'	'
Notes payable and commercial paper	93	278	208
Distributions to noncontrolling interests	-15	-25	-26
Contributions from noncontrolling Interests	9	76	'
Dividends paid	-2,188	-1,752	-1,329
Other	21	-5	-10
Net cash provided by (used in) financing activities	-1,327	267	1,202
Net increase (decrease) in cash and cash equivalents	77	-686	440
Cash and cash equivalents at beginning of period	1,424	2,110	1,670
Cash and cash equivalents at end of period	1,501	1,424	2,110
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	1,665	1,032	813
Cash paid for (received from) income taxes	-202	72	26
Merger with Progress Energy [Abstract]	'	'	'
Fair value of assets acquired	'	48,944	'
Liabilities assumed	'	30,873	'
Issuance of common stock	'	18,071	'
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	594	684	409
Duke Energy Carolinas [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	976	865	834
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,167	1,143	1,020
Equity component of AFUDC	-91	-154	-168
FERC mitigation costs	'	46	'
Community support and charitable contributions and other	14	56	'
(Gains) losses on sales of other assets	'	-12	-1
Impairment of other long-lived assets	'	'	12
Deferred income taxes	534	479	564
Voluntary opportunity cost deferral	'	-101	'
Accrued pension and other post-retirement benefit costs	38	41	32
Contributions to qualified pension plans	'	'	-33
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	-9	'	-91
Receivables	-12	22	22
Receivables from affiliated companies	-72	-1	88
Inventory	-9	-128	-177
Other current assets	-1	46	144
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	58	-51	120
Accounts payable to affiliated companies	33	-28	-39
Taxes accrued	4	-12	12
Other current liabilities	-40	165	-170
Other assets	-102	-117	-46
Other liabilities	-77	-126	-249
Net cash provided by (used in) operating activities	2,411	2,133	1,874
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-1,695	-1,908	-2,272
Purchases of available-for-sale securities	-2,405	-2,481	-2,227
Proceeds from sales and maturities of available-for-sale securities	2,363	2,445	2,179
Notes receivable from affiliated companies	160	541	-584
Change in restricted cash	'	'	2
Other	-24	-12	-13
Net cash (used in) provided by investing activities	-1,601	-1,415	-2,915
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	100	645	1,498
Payments for the redemption of long-term debt	-405	-1,177	-7
Dividends to parent	-499	-450	-299
Other	-2	-6	-15
Net cash provided by (used in) financing activities	-806	-988	1,177
Net increase (decrease) in cash and cash equivalents	4	-270	136
Cash and cash equivalents at beginning of period	19	289	153
Cash and cash equivalents at end of period	23	19	289
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	336	385	337
Cash paid for (received from) income taxes	-7	-38	-223
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	199	194	209
Progress Energy [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	675	407	582
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,041	897	850
Equity component of AFUDC	-50	-106	-103
Severance expense	0	38	0
FERC mitigation costs	0	71	0
Community support and charitable contributions and other	20	36	0
(Gains) losses on sales of other assets	2	-16	-5
Impairment of other long-lived assets	380	146	3
Deferred income taxes	616	263	353
Amounts to be refunded to customers	0	100	288
Accrued pension and other post-retirement benefit costs	172	179	124
Contributions to qualified pension plans	-250	-346	-331
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	55	7	-10
Receivables	-148	49	167
Receivables from affiliated companies	11	-15	0
Inventory	17	-71	-210
Other current assets	-156	2	-111
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	-81	175	-64
Accounts payable to affiliated companies	93	30	0
Taxes accrued	22	25	-16
Other current liabilities	61	81	67
Other assets	-243	-25	-67
Other liabilities	-115	-87	98
Net cash provided by (used in) operating activities	2,122	1,840	1,615
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-2,490	-2,366	-2,256
Purchases of available-for-sale securities	-2,558	-1,374	-5,017
Proceeds from sales and maturities of available-for-sale securities	2,513	1,325	4,970
Notes receivable from affiliated companies	-75	0	0
Insurance proceeds	0	7	79
Change in restricted cash	0	24	-24
Other	13	102	36
Net cash (used in) provided by investing activities	-2,597	-2,282	-2,212
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	845	2,074	1,286
Proceeds from the issuance of common stock related to employee benefit plans	0	6	53
Payments for the redemption of long-term debt	-1,196	-962	-1,010
Payments for the redemption of preferred stock	-96	0	0
Payments of short-term debt with original maturities greater than 90 days	0	-65	0
Proceeds from issuance of short-term debt with original maturities greater than 90 days	0	65	0
Notes payable and commercial paper	0	-671	667
Notes payable to affiliated companies	758	455	0
Distributions to noncontrolling interests	-3	-7	-7
Dividends paid	0	-445	-734
Other	-6	-7	-39
Net cash provided by (used in) financing activities	302	443	216
Net increase (decrease) in cash and cash equivalents	-173	1	-381
Cash and cash equivalents at beginning of period	231	230	611
Cash and cash equivalents at end of period	58	231	230
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	678	784	793
Cash paid for (received from) income taxes	-167	-4	-78
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	255	375	380
Asset retirement obligation additions and estimate revisions	0	837	-4
Capital expenditures financed through capital leases	0	140	0
Duke Energy Progress [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	500	272	516
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	685	676	654
Equity component of AFUDC	-42	-69	-71
Severance expense	0	18	0
FERC mitigation costs	0	71	0
Community support and charitable contributions and other	20	36	0
(Gains) losses on sales of other assets	-1	-1	-3
Impairment of other long-lived assets	22	0	3
Deferred income taxes	368	164	262
Accrued pension and other post-retirement benefit costs	72	70	43
Contributions to qualified pension plans	-63	-141	-217
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	-9	-25	-23
Receivables	-88	2	84
Receivables from affiliated companies	3	-4	8
Inventory	-26	-58	-182
Other current assets	-39	-24	116
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	-18	149	-22
Accounts payable to affiliated companies	27	47	-45
Taxes accrued	15	-5	-4
Other current liabilities	-86	23	40
Other assets	-74	-28	-38
Other liabilities	-78	-6	16
Net cash provided by (used in) operating activities	1,188	1,167	1,137
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-1,567	-1,525	-1,426
Purchases of available-for-sale securities	-901	-582	-572
Proceeds from sales and maturities of available-for-sale securities	856	532	515
Notes receivable from affiliated companies	0	0	2
Other	4	91	12
Net cash (used in) provided by investing activities	-1,608	-1,484	-1,469
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	845	988	495
Payments for the redemption of long-term debt	-451	-502	-2
Payments for the redemption of preferred stock	-62	0	0
Notes payable and commercial paper	0	-188	185
Notes payable to affiliated companies	98	333	31
Dividends to parent	0	-310	-585
Dividends paid on preferred stock	0	-3	-3
Other	-7	-3	1
Net cash provided by (used in) financing activities	423	315	122
Net increase (decrease) in cash and cash equivalents	3	-2	-210
Cash and cash equivalents at beginning of period	18	20	230
Cash and cash equivalents at end of period	21	18	20
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	217	249	199
Cash paid for (received from) income taxes	-94	19	-97
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	166	232	270
Asset retirement obligation additions and estimate revisions	0	698	-4
Capital expenditures financed through capital leases	0	140	0
Duke Energy Florida [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	325	266	314
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	335	197	174
Equity component of AFUDC	-8	-37	-32
Severance expense	0	6	0
(Gains) losses on sales of other assets	-1	-2	-2
Impairment of other long-lived assets	358	146	0
Deferred income taxes	368	142	234
Amounts to be refunded to customers	0	100	288
Accrued pension and other post-retirement benefit costs	79	71	52
Contributions to qualified pension plans	-133	-128	-112
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	55	73	-13
Receivables	-44	37	91
Receivables from affiliated companies	17	-13	-6
Inventory	42	-13	-28
Other current assets	-109	22	-160
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	-22	21	-45
Accounts payable to affiliated companies	-6	30	-37
Taxes accrued	18	15	-8
Other current liabilities	159	51	16
Other assets	-154	8	-7
Other liabilities	-74	-94	46
Net cash provided by (used in) operating activities	1,205	898	765
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-915	-809	-813
Purchases of available-for-sale securities	-1,656	-791	-4,435
Proceeds from sales and maturities of available-for-sale securities	1,658	791	4,438
Notes receivable from affiliated companies	207	-207	0
Insurance proceeds	0	7	76
Other	0	9	27
Net cash (used in) provided by investing activities	-706	-1,000	-707
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	0	642	296
Payments for the redemption of long-term debt	-435	-10	-309
Payments for the redemption of preferred stock	-34	0	0
Payments of short-term debt with original maturities greater than 90 days	0	-65	0
Proceeds from issuance of short-term debt with original maturities greater than 90 days	0	65	0
Notes payable and commercial paper	0	-233	233
Notes payable to affiliated companies	181	-8	0
Dividends to parent	-325	-170	-510
Dividends paid on preferred stock	0	-2	-2
Other	-1	-2	1
Net cash provided by (used in) financing activities	-614	217	-291
Net increase (decrease) in cash and cash equivalents	-115	115	-233
Cash and cash equivalents at beginning of period	131	16	249
Cash and cash equivalents at end of period	16	131	16
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	201	266	287
Cash paid for (received from) income taxes	-84	24	-83
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	88	139	106
Asset retirement obligation additions and estimate revisions	0	139	0
Duke Energy Ohio [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	102	175	194
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	357	342	338
Equity component of AFUDC	-1	-6	-5
(Gains) losses on sales of other assets	-5	-7	-5
Impairment of other long-lived assets	5	2	89
Deferred income taxes	98	61	190
Accrued pension and other post-retirement benefit costs	17	11	14
Contributions to qualified pension plans	'	'	-48
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	17	-5	-8
Receivables	-15	29	10
Receivables from affiliated companies	-39	61	98
Inventory	-3	15	11
Other current assets	-1	-62	-24
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	13	5	-33
Accounts payable to affiliated companies	15	-22	1
Taxes accrued	1	-24	8
Other current liabilities	14	-21	-3
Other assets	-6	6	-56
Other liabilities	-73	-116	47
Net cash provided by (used in) operating activities	496	444	818
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-434	-514	-499
Net proceeds from the sales of other assets, and sales of and collections on notes receivable	11	82	'
Notes receivable from affiliated companies	-56	400	79
Change in restricted cash	'	'	-26
Other	1	6	-3
Net cash (used in) provided by investing activities	-478	-26	-449
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	450	'	'
Payments for the redemption of long-term debt	-258	-556	-9
Notes payable to affiliated companies	-202	245	'
Dividends to parent	'	-175	-485
Other	-3	'	-4
Net cash provided by (used in) financing activities	-13	-486	-498
Net increase (decrease) in cash and cash equivalents	5	-68	-129
Cash and cash equivalents at beginning of period	31	99	228
Cash and cash equivalents at end of period	36	31	99
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	71	93	100
Cash paid for (received from) income taxes	9	18	-102
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	27	31	43
Transfer of Vermillion Generating Station	'	-28	'
Duke Energy Indiana [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES [Abstract]	'	'	'
Net income	358	-50	168
Adjustments to reconcile net income to net cash provided by operating activities: [Abstract]	'	'	'
Depreciation, amortization and accretion (including amortization of nuclear fuel)	346	393	395
Equity component of AFUDC	-15	-84	-88
Impairment of other long-lived assets	'	579	234
Deferred income taxes	304	-74	-63
Accrued pension and other post-retirement benefit costs	25	15	23
Contributions to qualified pension plans	'	'	-52
(Increase) decrease in [Abstract]	'	'	'
Net realized and unrealized mark-to-market and hedging transactions	-30	'	'
Receivables	3	6	25
Receivables from affiliated companies	-47	52	63
Inventory	-53	-50	-64
Other current assets	-40	-25	13
Increase (decrease) in [Abstract]	'	'	'
Accounts payable	32	18	-14
Accounts payable to affiliated companies	-4	-12	5
Taxes accrued	-30	-27	29
Other current liabilities	-5	6	-16
Other assets	-16	6	47
Other liabilities	-84	-37	-72
Net cash provided by (used in) operating activities	744	716	633
CASH FLOWS FROM INVESTING ACTIVITIES [Abstract]	'	'	'
Capital expenditures	-545	-718	-1,066
Purchases of available-for-sale securities	-11	-17	-11
Proceeds from sales and maturities of available-for-sale securities	7	18	8
Notes receivable from affiliated companies	-96	'	115
Change in restricted cash	'	'	6
Other	-3	-1	-5
Net cash (used in) provided by investing activities	-648	-718	-953
CASH FLOWS FROM FINANCING ACTIVITIES [Abstract]	'	'	'
Proceeds from the issuance of long-term debt	498	250	'
Payments for the redemption of long-term debt	-405	-7	-14
Notes payable to affiliated companies	-81	-219	300
Dividends to parent	-125	'	'
Other	-4	-2	-4
Net cash provided by (used in) financing activities	-117	22	282
Net increase (decrease) in cash and cash equivalents	-21	20	-38
Cash and cash equivalents at beginning of period	36	16	54
Cash and cash equivalents at end of period	15	36	16
Supplemental Disclosures [Abstract]	'	'	'
Cash paid for interest, net of amount capitalized	194	130	130
Cash paid for (received from) income taxes	46	57	90
Significant Non-cash Transactions [Abstract]	'	'	'
Accrued capital expenditures	73	67	110
Transfer of Vermillion Generating Station	'	$26	'

Consolidated_Statements_of_Equ

Consolidated Statements of Equity (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]

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]

Beginning Member's Equity at Dec. 31, 2010

$8,916

$8,938

($20)

($2)

Balance at Dec. 31, 2010

22,653

21,023

1,496

-18

-17

-60

22,522

131

10,027

7,332

2,805

-63

-62

10,023

5,180

2,130

3,083

-33

4,890

1,750

3,144

-4

5,464

762

5,570

-846

-22

3,567

1,358

2,200

Balance (in shares) at Dec. 31, 2010

443,000,000

Net income

1,714

1,706

834

582

516

314

194

168

Net income

578

575

[1]

Net income (loss) available to common stockholders

513

312

Other comprehensive income (loss), net of tax

-243

-142

-53

-49

-236

-7

-40

-79

-40

-38

-23

-6

-1

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

2,000,000

Common stock issuances, including dividend reinvestment and employee benefits

109

Stock-based compensation expense

Common stock dividends

-1,329

-628

Dividends to parent

-299

-585

-510

-485

Preferred stock dividends at stated rates

-3

-2

Changes in noncontrolling interest in subsidiaries

[2]

-39

Distributions to noncontrolling interests

-3

Tax dividend

-1

Total Member's Equity

9,454

9,473

-17

-2

Notes To Reconciliation Of Total Equity [Details]

Net income attributable to preferred shareholders

Balance at Dec. 31, 2011

22,865

21,132

1,873

-45

-71

-9

-109

22,772

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

2,368

Balance (in shares) at Dec. 31, 2011

445,000,000

Beginning Member's Equity at Dec. 31, 2011

9,454

Net income

299

266

152

128

-167

Balance at Mar. 31, 2012

Beginning Member's Equity at Dec. 31, 2011

9,454

9,473

-17

-2

Balance at Dec. 31, 2011

22,865

21,132

1,873

-45

-71

-9

-109

22,772

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

1,782

1,768

865

407

272

266

175

-50

Net income

403

400

[1]

Net income (loss) available to common stockholders

1,780

[3]

269

264

Other comprehensive income (loss), net of tax

-76

-71

-29

-72

-4

100

-2

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

-1,752

-369

Dividends to parent

-450

-310

-170

-175

Preferred stock dividends at stated rates

-3

-2

Changes in noncontrolling interest in subsidiaries

[2]

-17

Transfer of Vermillion Generating Station

-28

Deconsolidation of DS Cornerstone, LLC

[4]

-82

Contribution from noncontrolling interest in DS Cornerstone, LLC

[4]

Distributions to noncontrolling interests

-2

Contributions from noncontrolling Interests

Recapitalization for merger with Duke Energy

-7,436

7,436

Tax dividend

-2

Other

-1

Total Member's Equity

9,872

9,888

-15

-1

Notes To Reconciliation Of Total Equity [Details]

Net income attributable to preferred shareholders

-2

Balance at Dec. 31, 2012

40,941

39,279

1,889

-116

-100

-90

40,863

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

59,913,701

Beginning Member's Equity at Sep. 30, 2012

Net income

437

130

-45

Total Member's Equity

9,872

Balance at Dec. 31, 2012

40,941

10,185

5,127

4,799

5,166

762

3,708

Balance (in shares) at Dec. 31, 2012

704,000,000

100

160,000,000

100

89,663,086

59,913,701

Beginning Member's Equity at Dec. 31, 2012

9,872

Net income

634

244

154

110

-21

Balance at Mar. 31, 2013

Beginning Member's Equity at Dec. 31, 2012

9,872

9,888

-15

-1

Balance at Dec. 31, 2012

40,941

39,279

1,889

-116

-100

-90

40,863

10,185

7,465

2,783

-42

-25

10,181

5,127

2,968

4,799

3,037

5,166

762

-477

-1

3,708

2,318

Balance (in shares) at Dec. 31, 2012

704,000,000

100

160,000,000

100

89,663,086

59,913,701

Net income

2,676

2,665

976

675

500

325

102

358

Net income

675

672

Net income (loss) available to common stockholders

500

325

Other comprehensive income (loss), net of tax

-99

-191

-93

-6

-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

-2,188

Dividends to parent

-499

-325

-125

Preferred stock dividends at stated rates

Premium on the redemption of preferred stock of subsidiaries

-3

-2

-1

Changes in noncontrolling interest in subsidiaries

[2]

-14

Distributions to noncontrolling interests

-3

Contributions from noncontrolling Interests

Other additional paid in capital adjustments

Total Member's Equity

10,350

10,365

-14

-1

Notes To Reconciliation Of Total Equity [Details]

Net income attributable to preferred shareholders

Balance at Dec. 31, 2013

41,408

39,365

2,363

-307

-40

-52

41,330

10,864

7,467

3,452

-43

-16

10,860

5,625

2,159

3,466

4,797

1,762

3,036

-1

5,269

762

4,882

-375

3,939

1,384

2,551

Balance (in shares) at Dec. 31, 2013

706,000,000

100

160,000,000

100

89,663,086

59,913,701

Beginning Member's Equity at Sep. 30, 2013

Net income

692

209

196

138

Total Member's Equity

10,350

Balance at Dec. 31, 2013

$41,408

$10,864

$5,625

$2,159

$4,797

$1,762

$5,269

$762

$4,882

$3,939

$1,384

Balance (in shares) at Dec. 31, 2013

706,000,000

100

160,000,000

100

89,663,086

59,913,701

[1]

For the year ended December 31, 2012, consolidated net income of $407 million included $4 million attributable to preferred shareholders of subsidiaries. For the year ended December 31, 2011, consolidated net income of $582 million included $4 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]

Includes $15 million, $23 million and $26 million in cash distributions to noncontrolling interests in 2013, 2012 and 2011, respectively.

[3]

For the year ended December 31, 2012, consolidated net income of $1,782 million includes $2 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.

[4]

Refer to Note 2 for further information on the deconsolidation of DS Cornerstone, LLC.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
Summary of Significant Accounting Policies	Dec. 31, 2013
Organization And Basis of Presentation [Abstract]	'
Summary of Significant Accounting Policies	'
	Index to Combined Notes To Consolidated Financial Statements

	The notes to the consolidated financial statements are a combined presentation. The following list indicates the registrants to which the notes apply.

			Applicable Notes
	Registrant		1	2	3	4	5	6	7	8	9	10	11	12	13	14	15	16	17	18	19	20	21	22	23	24	25
	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. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	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 U.S. and Latin America primarily through its direct and indirect subsidiaries. Duke Energy's subsidiaries include its wholly owned 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.
	On July 2, 2012, Duke Energy merged with Progress Energy, with Duke Energy continuing as the surviving corporation. Progress Energy became a subsidiary of Duke Energy and Progress Energy's regulated utility subsidiaries, Duke Energy Progress (formerly Carolina Power & Light Company d/b/a Progress Energy Carolinas, Inc.) and Duke Energy Florida (formerly Florida Power Corporation d/b/a Progress Energy Florida, Inc.), became indirect subsidiaries of Duke Energy. Duke Energy's consolidated financial statements include Progress Energy, Duke Energy Progress and Duke Energy Florida activity beginning July 2, 2012. The impacts of acquisition accounting from Progress Energy's merger with Duke Energy were recorded by Duke Energy and were not reflected on the financial statements of Progress Energy, Duke Energy Progress and Duke Energy Florida. See Note 2 for additional information regarding the merger. On July 2, 2012, just prior to the close of the merger, Duke Energy executed a one-for-three reverse stock split with respect to the issued and outstanding shares of Duke Energy common stock. All per-share amounts included in this Form 10-K are presented as if the stock split had been effective from the beginning of the earliest period presented.
	The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to the 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.
	These Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries where the respective Duke Energy Registrants have control. These Consolidated Financial Statements also reflect the Duke Energy Registrants' proportionate share of jointly owned generation and transmission facilities.
	Duke Energy Carolinas 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 Carolinas is subject to the regulatory provisions of the North Carolina Utilities Commission (NCUC), Public Service Commission of South Carolina (PSCSC), U.S. Nuclear Regulatory Commission (NRC) and FERC. Substantially all of Duke Energy Carolinas' operations qualify for regulatory accounting.
	Progress Energy is a public utility 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. Substantially all of Progress Energy's operations qualify for regulatory accounting.
	Duke Energy Progress 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, PSCSC, NRC and FERC. Substantially all of Duke Energy Progress' operations qualify for regulatory accounting.
	Duke Energy Florida 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 jurisdiction of the Florida Public Service Commission (FPSC), NRC and FERC. Substantially all of Duke Energy Florida's operations qualify for regulatory accounting.
	Duke Energy Ohio is a 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's principal lines of business include transmission and distribution of electricity and the sale of and/or transportation of natural gas. Duke Energy Ohio also generates and sells power into wholesale energy markets. 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), Kentucky Public Service Commission (KPSC) and FERC. Duke Energy Ohio applies regulatory accounting to a portion of its operations.
	Duke Energy Indiana 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 qualify for regulatory accounting.
	Certain prior year amounts have been reclassified to conform to the current year presentation.
	Other Current and Non-Current Assets and Liabilities
	Other within Current Assets includes the current portion of deferred tax assets, which are disclosed in Note 22. Additionally, the following are included in Other within Current Assets or Current Liabilities in the Consolidated Balance Sheets of the Duke Energy Registrants at December 31, 2013 and 2012. The amounts presented exceeded 5 percent of current assets or 5 percent of current liabilities unless otherwise noted.

					December 31,
	(in millions)		Location		2013			2012
	Duke Energy
	Accrued compensation		Current Liabilities		$	621		$	725
	Duke Energy Carolinas
	Accrued compensation		Current Liabilities		$	198		$	203
	Collateral liabilities		Current Liabilities			120			105
	Progress Energy
	Customer deposits		Current Liabilities		$	349		$	342
	Accrued compensation		Current Liabilities			214			304
	Derivative liabilities		Current Liabilities			—			221
	Duke Energy Progress
	Customer deposits		Current Liabilities		$	129		$	120
	Accrued compensation		Current Liabilities			121			160
	Duke Energy Florida
	Customer deposits		Current Liabilities		$	220		$	222
	Accrued compensation		Current Liabilities			65			95
	Derivative liabilities		Current Liabilities			—			127
	Duke Energy Ohio
	Collateral assets		Current Assets		$	122		$	99
	Duke Energy Indiana
	Federal income taxes receivable		Current Assets		$	56		$	—
	Accrued compensation^(a)		Current Liabilities			25			23
	Collateral liabilities^(a)		Current Liabilities			40			37
	Derivative liabilities		Current Liabilities			—			63

	(a)	Does not exceed 5 percent of Total current liabilities on the Consolidated Balance Sheets at December 31, 2012.

	Preferred Stock
	In March 2013, Duke Energy Progress and Duke Energy Florida redeemed all series of their outstanding preferred stock at prices ranging from $101.00 to $110.00 per share for Duke Energy Progress and $101.00 to $104.25 per share for Duke Energy Florida plus accrued dividends for all series. Duke Energy Progress and Duke Energy Florida redeemed the shares for $62 million and $34 million, respectively.
	Discontinued Operations
	For the year ended December 31, 2013, Duke Energy's and Progress Energy's Income From Discontinued Operations, net of tax was primarily due to tax benefits related to prior sales of diversified businesses. For the year ended December 31, 2012, Duke Energy's and Progress Energy's Income From Discontinued Operations, net of tax was primarily related to resolution of litigation associated with Progress Energy's former synthetic fuel operations and reversal of certain environmental indemnification liabilities for which the indemnification period expired during 2012. See Note 5 for more information regarding the former synthetic fuel operations.
	Amounts Attributable to Controlling Interests
	Income From Discontinued Operations, net of tax presented on the respective Consolidated Statements of Operations for Duke Energy and Progress Energy is attributable to controlling interests for all periods presented. Other comprehensive income presented on Progress Energy's Consolidated Statements of Operations and Comprehensive Income are attributable to controlling interests for all periods presented.
Significant Accounting Policies
Use of Estimates
In preparing financial statements that conform to generally accepted accounting principles (GAAP) in the U.S., the Duke Energy Registrants 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.
Regulatory Accounting
The majority of the Duke Energy Registrants' operations are subject to price regulation for the sale of electricity and gas by state utility commissions or FERC. When prices are set on the basis of specific costs of the regulated operations and an effective franchise is in place such that sufficient gas or electric services can be sold to recover those costs, the Duke Energy Registrants apply regulatory accounting. Regulatory accounting changes the timing of the recognition of costs or revenues relative to a company that does not apply regulatory accounting. As a result, Regulatory assets and Regulatory liabilities are recognized on the Consolidated Balance Sheets. Regulatory assets and liabilities are amortized consistent with the treatment of the related cost in the ratemaking process. See Note 4 for further information.
Regulated Fuel Costs and Purchased Power
The Duke Energy Registrants utilize cost-tracking mechanisms, commonly referred to as fuel adjustment clauses. These clauses allow for the recovery of fuel and fuel-related costs and portions of purchased power costs through surcharges on customer rates. The difference between the costs incurred and the surcharge revenues is recorded as an adjustment to Fuel used in electric generation and purchased power — regulated or Operating Revenues – Regulated electric on the Consolidated Statements of Operations with an off-setting impact on regulatory assets or liabilities.
Cash and Cash Equivalents
All highly liquid investments with maturities of three months or less at the date of acquisition are considered cash equivalents. At December 31, 2013, $1,086 million of Duke Energy's total cash and cash equivalents is held by entities domiciled in foreign jurisdictions and is forecasted to be used to fund international operations and investments.
Restricted Cash
The Duke Energy Registrants have restricted cash related primarily to collateral assets, escrow deposits, and variable interest entities (VIEs). Restricted cash balances are reflected in Other within Current Assets and in Other within Investments and Other Assets on the Consolidated Balance Sheets. At December 31, 2013 and 2012, Duke Energy had restricted cash totaling $307 million and $574 million, respectively.
Inventory
Inventory is used for operations and is recorded primarily using the average cost method. Inventory related to regulated operations is valued at historical cost. Inventory related to nonregulated operations is valued at the lower of cost or market. Materials and supplies are recorded as inventory when purchased and subsequently charged to expense or capitalized to property, plant and equipment when installed. Reserves are established for excess and obsolete inventory. The components of inventory are presented in the tables below.

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Materials and supplies		$	1,901		$	654		$	854		$	567		$	287		$	117		$	193
Coal held for electric generation			1,018			374			334			187			147			65			238
Oil, gas and other fuel held for electric generation			331			37			236			99			137			47			3
Total inventory		$	3,250		$	1,065		$	1,424		$	853		$	571		$	229		$	434

		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Materials and supplies		$	1,691		$	535		$	768		$	499		$	269		$	135		$	161
Coal held for electric generation			1,187			488			392			232			160			82			216
Oil, gas and other fuel held for electric generation			345			39			281			97			184			10			3
Total inventory		$	3,223		$	1,062		$	1,441		$	828		$	613		$	227		$	380

Investments in Debt and Equity Securities
The Duke Energy Registrants classify investments into two categories — trading and available-for-sale. Both categories are recorded at fair value on the Consolidated Balance Sheets. Realized and unrealized gains and losses on trading securities are included in earnings. For certain investments of regulated operations such as the Nuclear Decommissioning Trust Fund (NDTF), realized and unrealized gains and losses (including any other-than-temporary impairments) on available-for-sale securities are recorded as a regulatory asset or liability. Otherwise, unrealized gains and losses are included in Accumulated Other Comprehensive Income (AOCI), unless other-than-temporarily impaired. Other-than-temporary impairments for equity securities and the credit loss portion of debt securities of nonregulated operations are included in earnings. Investments in debt and equity securities are classified as either current or noncurrent based on management's intent and ability to sell these securities, taking into consideration current market liquidity. See Note 15 for further information.
Goodwill and Intangible Assets
Goodwill
Duke Energy, Progress Energy and Duke Energy Ohio perform annual goodwill impairment tests as of August 31 each year at the reporting unit level, which is determined to be an operating segment or one level below. Duke Energy, Progress Energy and Duke Energy Ohio update these tests 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.
In 2012, Progress Energy changed its goodwill impairment testing date from October 31 to August 31 to better align its annual goodwill impairment testing procedure with those of Duke Energy. The change had no impact on goodwill. Neither the change in the goodwill impairment testing date nor the merger resulted in any changes to the Progress Energy reporting units.
Intangible Assets
Intangible assets are included in Other in Investments and Other Assets on the Consolidated Balance Sheets. Generally, intangible assets are amortized using an amortization method that reflects the pattern in which the economic benefits of the intangible asset are consumed, or on a straight-line basis if that pattern is not readily determinable. Amortization of intangibles is reflected in Depreciation and amortization in the Consolidated Statements of Operations. Intangible assets are subject to impairment testing and if impaired, the carrying value is accordingly reduced.
Emission allowances permit the holder of the allowance to emit certain gaseous by-products of fossil fuel combustion, including sulfur dioxide (SO2) and nitrogen oxide (NOx). Allowances are issued by the U.S. Environmental Protection Agency (EPA) at zero cost and may also be bought and sold via third-party transactions. Allowances allocated to or acquired by the Duke Energy Registrants are held primarily for consumption. Carrying amounts for emission allowances are based on the cost to acquire the allowances or, in the case of a business combination, on the fair value assigned in the allocation of the purchase price of the acquired business.
Renewable energy certificates are used to measure compliance with renewable energy standards and are held primarily for consumption.
See Note 11 for further information.
Long-Lived Asset Impairments
The Duke Energy Registrants evaluate long-lived assets, excluding goodwill, for impairment when circumstances indicate the carrying value of those assets may not be recoverable. An impairment exists when a long-lived asset's carrying value exceeds the estimated undiscounted cash flows expected to result from the use and eventual disposition of the asset. The estimated cash flows may be based on alternative expected outcomes that are probability weighted. If the carrying value of the long-lived asset is not recoverable based on these estimated future undiscounted cash flows, the carrying value of the asset is written-down to its then-current estimated fair value and an impairment charge is recognized.
The Duke Energy Registrants assess fair value of long-lived assets using various methods, including recent comparable third-party sales, internally developed discounted cash flow analysis and analysis from outside advisors. Significant changes in commodity prices, the condition of an asset or management's interest in selling the asset are generally viewed as triggering events to re-assess cash flows. See Note 11 for further information.
Property, Plant and Equipment
Property, plant and equipment are stated at the lower of depreciated historical cost net of any disallowances or fair value, if impaired. The Duke Energy Registrants capitalize all construction-related direct labor and material costs, as well as indirect construction costs such as general engineering, taxes and financing costs. See “Allowance for Funds Used During Construction (AFUDC) and Interest Capitalized” for information on capitalized financing costs. Costs of renewals and betterments that extend the useful life of property, plant and equipment are also capitalized. The cost of repairs, replacements and major maintenance projects, which do not extend the useful life or increase the expected output of the asset, are expensed as incurred. Depreciation is generally computed over the estimated useful life of the asset using the composite straight-line method. Depreciation studies are conducted periodically to update composite rates and are approved by state utility commissions and/or the FERC when required. The composite weighted-average depreciation rates, excluding nuclear fuel, are included in the table that follows.

		Years Ended December 31,
		2013			2012			2011
Duke Energy		2.8	%		2.9	%		3.2	%
Duke Energy Carolinas		2.8	%		2.8	%		2.6	%
Progress Energy		2.5	%		2.6	%		2.3	%
Duke Energy Progress		2.5	%		2.7	%		2.1	%
Duke Energy Florida		2.4	%		2.5	%		2.4	%
Duke Energy Ohio		3.3	%		3.2	%		3.5	%
Duke Energy Indiana		2.8	%		3.3	%		3.4	%

In general, when the Duke Energy Registrants retire regulated property, plant and equipment, original cost plus the cost of retirement, less salvage value, is charged to accumulated depreciation. However, when it becomes probable a regulated asset will be retired substantially in advance of its original expected useful life or is abandoned, the cost of the asset and the corresponding accumulated depreciation is recognized as a separate asset. If the asset is still in operation, the net amount is classified as Generation facilities to be retired, net on the Consolidated Balance Sheets. If the asset is no longer operating, the net amount is classified in Regulatory Assets on the Consolidated Balance Sheets. The carrying value of the asset is based on historical cost if the Duke Energy Registrants are allowed to recover the remaining net book value and a return equal to at least the incremental borrowing rate. If not, an impairment is recognized to the extent the net book value of the asset exceeds the present value of future revenues discounted at the incremental borrowing rate.
When the Duke Energy Registrants sell entire regulated operating units, or retire or sell nonregulated properties, the original cost and accumulated depreciation and amortization balances are removed from Property, Plant and Equipment on the Consolidated Balance Sheets. Any gain or loss is recorded in earnings, unless otherwise required by the applicable regulatory body.
See Note 10 for further information.
Nuclear Fuel
Nuclear fuel is classified as Property, Plant and Equipment on the Consolidated Balance Sheets. Nuclear fuel in the front-end fuel processing phase is considered work in progress and not amortized until placed in service. Amortization of nuclear fuel is included within Fuel used in electric generation and purchased power – regulated in the Consolidated Statements of Operations. Amortization is recorded using the units-of-production method.
Allowance for Funds Used During Construction (AFUDC) and Interest Capitalized
For regulated operations, the debt and equity costs of financing the construction of property, plant and equipment are reflected as AFUDC and capitalized as a component of the cost of property, plant and equipment. AFUDC equity is reported on the Consolidated Statements of Operations as non-cash income in Other income and expenses, net. AFUDC debt is reported as a non-cash offset to Interest Expense. After construction is completed, the Duke Energy Registrants are permitted to recover these costs through their inclusion in rate base and the corresponding subsequent depreciation or amortization of those regulated assets.
AFUDC equity, a permanent difference for income taxes, reduces the effective tax rate when capitalized and increases the effective tax rate when depreciated or amortized. See Note 22 for additional information.
For nonregulated operations, interest is capitalized during the construction phase with an offsetting non-cash credit to Interest Expense on the Consolidated Statements of Operations.
Asset Retirement Obligations
Asset retirement obligations are recognized for legal obligations associated with the retirement of property, plant and equipment. Substantially all asset retirement obligations are related to regulated operations. When recording an asset retirement obligation, the present value of the projected liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is accreted over time. The present value of the liability is added to the cost of the associated asset and depreciated over the remaining life of the asset.
The present value of the initial obligation and subsequent updates are based on discounted cash flows, which include estimates regarding timing of future cash flows, selection of discount rates and cost escalation rates, among other factors. These estimates are subject to change. Depreciation expense is adjusted prospectively for any changes to the carrying amount of the associated asset. The Duke Energy Registrants receive amounts to fund the cost of the asset retirement obligation for regulated operations through a combination of regulated revenues and NDTF. As a result, the net of amounts recovered in regulated revenues, earnings on the NDTF, accretion expense and depreciation of the associated asset is deferred as a regulatory asset or liability.
Obligations for nuclear decommissioning are based on site-specific cost studies. Duke Energy Carolinas and Duke Energy Progress assume prompt dismantlement of the nuclear facilities after operations are ceased. Duke Energy Florida assumes Crystal River Nuclear Station – Unit 3 (Crystal River Unit 3) will be placed into a safe storage configuration until eventual dismantlement begins in approximately 60 years. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida also assume that spent fuel will be stored on site until such time that it can be transferred to a U.S. Department of Energy (DOE) facility.
See Note 9 for further information.
Revenue Recognition and Unbilled Revenue
Revenues on sales of electricity and gas are recognized when service is provided. Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy delivered but not yet billed. Unbilled revenues can vary significantly from period to period as a result of seasonality, weather, customer usage patterns and meter reading schedules.
Unbilled revenues are included within Receivables and Restricted receivables of variable interest entities on the Consolidated Balance Sheets as shown in the following table.

		December 31,
(in millions)		2013			2012
Duke Energy		$	937		$	920
Duke Energy Carolinas			323			315
Progress Energy			189			187
Duke Energy Progress			120			112
Duke Energy Florida			69			74
Duke Energy Ohio			55			47
Duke Energy Indiana			5			3

Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail and wholesale accounts receivable, including receivables for unbilled revenues, to an affiliate, Cinergy Receivables Company, LLC (CRC) and account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 17 for further information. These receivables for unbilled revenues are shown in the table below.

		December 31,
(in millions)		2013			2012
Duke Energy Ohio		$	89		$	90
Duke Energy Indiana			144			132

Allowance for Doubtful Accounts

Allowances for doubtful accounts are presented in the following table.

		December 31,
(in millions)		2013			2012			2011
Allowance for Doubtful Accounts
Duke Energy		$	30		$	34		$	35
Duke Energy Carolinas			3			3			3
Progress Energy			14			16			27
Duke Energy Progress			10			9			9
Duke Energy Florida			4			7			18
Duke Energy Ohio			2			2			16
Duke Energy Indiana			1			1			1
Allowance for Doubtful Accounts - VIEs
Duke Energy		$	43		$	44		$	40
Duke Energy Carolinas			6			6			6

Derivatives and Hedging
Derivative and non-derivative instruments may be used in connection with commodity price, interest rate and foreign currency risk management activities, including swaps, futures, forwards and options. All derivative instruments except those that qualify for the normal purchase/normal sale (NPNS) exception are recorded on the Consolidated Balance Sheets at their fair value. Qualifying derivative instruments may be designated as either cash flow hedges or fair value hedges. Other derivative instruments (undesignated contracts) either have not been designated or do not qualify as hedges. The effective portion of the change in the fair value of cash flow hedges is recorded in AOCI. The effective portion of the change in the fair value of a fair value hedge is offset in net income by changes in the hedged item. For activity subject to regulatory accounting, gains and losses on derivative contracts are reflected as regulatory assets or liabilities and not as other comprehensive income or current period income. As a result, changes in fair value of these derivatives have no immediate earnings impact.
Formal documentation, including transaction type and risk management strategy, is maintained for all contracts accounted for as a hedge. At inception and at least every three months thereafter, the hedge contract is assessed to see if it is highly effective in offsetting changes in cash flows or fair values of hedged items.
See Note 14 for further information.
Captive Insurance Reserves
Duke Energy has captive insurance subsidiaries that provide coverage, on an indemnity basis, to the Subsidiary Registrants as well as certain third parties, on a limited basis, for various business risks and losses, such as property, workers' compensation and general liability. Liabilities include provisions for estimated losses incurred but not yet reported (IBNR), as well as estimated provisions for known claims. IBNR reserve estimates are primarily based upon historical loss experience, industry data and other actuarial assumptions. Reserve estimates are adjusted in future periods as actual losses differ from experience.
Duke Energy, through its captive insurance entities, also has reinsurance coverage with third parties for certain losses above a per occurrence and/or aggregate retention. Receivables for reinsurance coverage are recognized when realization is deemed probable.
Unamortized Debt Premium, Discount and Expense
Premiums, discounts and expenses incurred with the issuance of outstanding long-term debt are amortized over the term of the debt issue. Call premiums and unamortized expenses associated with refinancing higher-cost debt obligations used to finance regulated assets are amortized. Amortization expense is recorded as Interest Expense in the Consolidated Statements of Operations and is reflected as Depreciation, amortization and accretion within Net cash provided by operating activities on the Consolidated Statements of Cash Flows.
Loss Contingencies and Environmental Liabilities
Contingent losses are recorded when it is probable a loss has occurred and can be reasonably estimated. When a range of the probable loss exists and no amount within the range is a better estimate than any other amount, the minimum amount in the range is recorded. Unless otherwise required by GAAP, legal fees are expensed as incurred.
Environmental liabilities are recorded on an undiscounted basis when environmental remediation or other liabilities becomes probable and can be reasonably estimated. Environmental expenditures related to past operations that do not generate current or future revenues are expensed. Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Certain environmental expenditures receive regulatory accounting treatment and are recorded as regulatory assets.
See Notes 4 and 5 for further information.
Pension and Other Post-Retirement Benefit Plans
Duke Energy maintains qualified, non-qualified and other post-retirement benefit plans. Eligible employees of the Subsidiary Registrants participate in the respective qualified, non-qualified and other post-retirement benefit plans and are allocated their proportionate share of benefit costs. See Note 21 for further information, including significant accounting policies associated with these plans.
Severance and Special Termination Benefits
Duke Energy has an ongoing severance plan under which, in general, the longer a terminated employee worked prior to termination the greater the amount of severance benefits. A liability for involuntary severance is recorded once an involuntary severance plan is committed to by management, or sooner, if involuntary severances are probable and can be reasonably estimated. For involuntary severance benefits incremental to its ongoing severance plan benefits, the fair value of the obligation is expensed at the communication date if there are no future service requirements, or over the required future service period. From time to time, Duke Energy offers special termination benefits under voluntary severance programs. Special termination benefits are recorded immediately upon employee acceptance absent a significant retention period. Otherwise, the cost is recorded over the remaining service period. Employee acceptance of voluntary severance benefits is determined by management based on the facts and circumstances of the benefits being offered. See Note 19 for further information.
Guarantees
Liabilities are recognized at the time of issuance or material modification of a guarantee for the estimated fair value of the obligation it assumes. Fair value is estimated using a probability-weighted approach. The obligation is reduced over the term of the guarantee or related contract in a systematic and rational method as risk is reduced. Any additional contingent loss for guarantee contracts subsequent to the initial recognition of a liability is accounted for and recognized at the time a loss is probable and can be reasonably estimated. See Note 7 for further information.
Stock-Based Compensation
Stock-based compensation represents costs related to stock-based awards granted to employees. Duke Energy recognizes stock-based compensation based upon the estimated fair value of awards, net of estimated forfeitures at the date of issuance. The recognition period for these costs begin at either the applicable service inception date or grant date and continues throughout the requisite service period, or for certain share-based awards until the employee becomes retirement eligible, if earlier. Compensation cost is recognized as expense or capitalized as a component of property, plant and equipment. See Note 20 for further information.
Income Taxes
Duke Energy and its subsidiaries file a consolidated federal income tax return and other state and foreign jurisdictional returns. The Subsidiary Registrants entered into a tax-sharing agreement with Duke Energy and income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. Deferred income taxes have been provided for temporary differences between GAAP and tax bases of assets and liabilities because the differences create taxable or tax-deductible amounts for future periods. Deferred taxes are not provided on translation gains and losses when earnings of a foreign operation are expected to be indefinitely reinvested. Investment tax credits (ITC) associated with regulated operations are deferred and amortized as a reduction of income tax expense over the estimated useful lives of the related properties.
Positions taken or expected to be taken on tax returns, including the decision to exclude certain income or transactions from a return, are recognized in the financial statements when it is more likely than not the tax position can be sustained based solely on the technical merits of the position. The largest amount of tax benefit that is greater than 50 percent likely of being effectively settled is recorded. Management considers a tax position effectively settled when: (i) the taxing authority has completed its examination procedures, including all appeals and administrative reviews; (ii) the Duke Energy Registrants do not intend to appeal or litigate the tax position included in the completed examination; and (iii) it is remote the taxing authority would examine or re-examine the tax position. The amount of a tax return position that is not recognized in the financial statements is disclosed as an unrecognized tax benefit. These unrecognized tax benefits may impact the financial statements through increasing income taxes payable, reducing income tax refunds receivable or changing deferred taxes.
Tax-related interest and penalties are recorded in Interest Expense and Other Income and Expenses, net, in the Consolidated Statements of Operations.
See Note 22 for further information.
Accounting for Renewable Energy Tax Credits and Grants
When Duke Energy elects either an ITC or a cash grant on wind or solar facilities, it reduces the basis of the property recorded on the Consolidated Balance Sheets by the amount of the ITC or cash grant and, therefore, the ITC or grant benefit is recognized through reduced depreciation expense. Additionally, certain tax credits and government grants received provide for initial tax depreciable base in excess of the book carrying value equal to one half of the ITC or government grant. Deferred tax benefits are recorded as a reduction to income tax expense in the period that the basis difference is created.
Excise Taxes
Certain excise taxes levied by state or local governments are required to be paid even if not collected from the customer. These taxes are recognized on a gross basis. Otherwise, the taxes are accounted for net. Excise taxes accounted for on a gross basis as Property and other taxes in the Consolidated Statements of Operations were as follows.

		Years Ended December 31,
(in millions)			2013			2012			2011
Duke Energy		$	602		$	466		$	293
Duke Energy Carolinas			164			161			153
Progress Energy			304			317			315
Duke Energy Progress			115			113			110
Duke Energy Florida			189			205			205
Duke Energy Ohio			105			102			109
Duke Energy Indiana			29			33			31

On July 23, 2013, North Carolina House Bill 998 (HB 998) was signed into law. HB 998 repeals the utility franchise tax effective July 1, 2014. The utility franchise tax was 3.22 percent gross receipts tax on sales of electricity. The result of this change in law will be an annual reduction in excise taxes of approximately $160 million for Duke Energy Carolinas and approximately $110 million for Duke Energy Progress. HB 998 also increases sales tax on electricity from 3 percent to 7 percent effective July 1, 2014. HB 998 requires the NCUC to adjust retail electric rates for the elimination of the utility franchise tax, changes due to the increase in sales tax on electricity, and the resulting change in liability of utility companies under the general franchise tax.

Foreign Currency Translation
The local currencies of most of Duke Energy's foreign operations have been determined to be their functional currencies. However, certain foreign operations' functional currency has been determined to be the U.S. Dollar, based on an assessment of the economic circumstances of the foreign operation. Assets and liabilities of foreign operations whose functional currency is not the U.S. Dollar, are translated into U.S. Dollars at the exchange rates in effect at period end. Translation adjustments resulting from changes in exchange rates are included in AOCI. Revenue and expense accounts are translated at average exchange rates during the year. Gains and losses arising from balances and transactions denominated in currencies other than the local currency are included in the results of operations when they occur.
Dividend Restrictions and Unappropriated Retained Earnings
Duke Energy does not have any legal, regulatory or other restrictions on paying common stock dividends to shareholders. However, as further described in Note 4, due to conditions established by regulators in conjunction with merger transaction approvals, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana have restrictions on paying dividends or otherwise advancing funds to Duke Energy. At December 31, 2013 and 2012, an insignificant amount of Duke Energy's consolidated Retained earnings balance represents undistributed earnings of equity method investments.
New Accounting Standards
The new accounting standards that were adopted for 2013, 2012 and 2011 had no significant impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. Disclosures have been enhanced to provide a discussion and tables on derivative contracts subject to enforceable master netting agreements and a table of quantitative disclosures about unobservable inputs. See Notes 14 and 16 for further information.
There are no Accounting Standards Updates that have been issued but not yet adopted as of December 31, 2013, that are expected to significantly impact the presentation or results of operations, cash flows or financial position or disclosures of the Duke Energy Registrants.

Acquisitions_Dispositions_and_

Acquisitions, Dispositions and Sales of Other Assets	12 Months Ended
Acquisitions, Dispositions and Sales of Other Assets	Dec. 31, 2013
Acquisitions And Sales Of Other Assets [Abstract]	'
Acquisitions, Dispositions And Sales Of Other Assets	'
	2. ACQUISITIONS, DISPOSITIONS AND SALES OF OTHER ASSETS
	ACQUISITIONS
	The Duke Energy Registrants consolidate assets and liabilities from acquisitions as of the purchase date, and include earnings from acquisitions in consolidated earnings after 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.
	The merger between Duke Energy and Progress Energy provides increased scale and diversity with potentially enhanced access to capital over the long term and a greater ability to undertake the significant construction programs necessary to respond to increasing environmental regulation, plant retirements and customer demand growth. Duke Energy's business risk profile is expected to improve over time due to the increased proportion of the business that is regulated. Additionally, cost savings, efficiencies and other benefits are expected from the combined operations.
	Purchase Price
	Total consideration transferred was based on the closing price of Duke Energy common shares on July 2, 2012, and was calculated as shown in the following table.

	(dollars in millions, except per share amounts; shares in thousands)
	Progress Energy common shares outstanding at July 2, 2012		296,116
	Exchange ratio		0.87083
	Duke Energy common shares issued for Progress Energy common shares outstanding		257,867
	Closing price of Duke Energy common shares on July 2, 2012	$	69.84
	Purchase price for common stock	$	18,009
	Fair value of outstanding earned stock compensation awards		62
	Total purchase price	$	18,071

	Progress Energy's stock-based compensation awards, including performance shares and restricted stock, were replaced with Duke Energy awards upon consummation of the merger. In accordance with accounting guidance for business combinations, a portion of the fair value of these awards is included in the purchase price as it represents consideration transferred in the merger.
	Purchase Price Allocation
	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. Estimates and assumptions include the projected timing and amount of future cash flows, discount rates reflecting risk inherent in future cash flows, and future market prices.
	Additionally the February 5, 2013 announcement of the decision to retire 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 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. 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 other post-retirement benefits (OPEB) plans, and the wholesale portion of Crystal River Unit 3, fair values of tangible and intangible assets and liabilities subject to these rate-setting provisions approximate their carrying values. Accordingly, assets acquired and liabilities assumed and pro forma financial information do not reflect any net adjustments related to these amounts. The difference between fair value and pre-merger carrying amounts for long-term debt, asset retirement obligations, capital leases and pension and OPEB plans for regulated operations were recorded as Regulatory assets.
	The excess of purchase price over 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 long-term potential for enhanced access to capital as a result of increased scale and diversity, opportunities for synergies, and an improved risk profile. Goodwill resulting from the merger was allocated entirely to the Regulated Utilities 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 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		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 preliminary fair values of assets acquired and liabilities assumed as of 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 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 purchase accounting adjustments recorded to earnings during the year ended December 31, 2013, or for the six months ended December 31, 2012.
	Pro Forma Financial Information
	The following unaudited pro forma financial information reflects the consolidated results of operations of Duke Energy and 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 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 period have been excluded from pro forma earnings presented below. After-tax non-recurring merger consummation, integration and other costs incurred by both Duke Energy and Progress Energy were $413 million and $85 million for the years ended 2012 and 2011, respectively. The pro forma financial information also excludes potential future cost savings or non-recurring charges related to the merger.

				Years Ended December 31,
	(in millions, except per share amounts)			2012		2011
	Revenues			$	23,976	$	23,445
	Net Income Attributable to Duke Energy Corporation				2,417		2,397
	Basic and Diluted Earnings Per Share				3.43		3.41

	Accounting Charges Related to the Merger Consummation
	The following pretax consummation charges were recognized upon closing of the merger and are included in the Duke Energy Registrants' Consolidated Statements of Operations and Comprehensive Income for the year ended December 31, 2012.

	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	FERC Mitigation	$	117	$	46	$	71	$	71	$	―	$	―	$	―
	Severance costs		196		63		82		55		27		21		18
	Community support, charitable contributions and other		169		79		74		63		11		7		6
	Total	$	482	$	188	$	227	$	189	$	38	$	28	$	24

	FERC Mitigation charges reflect the portion of transmission project costs probable of disallowance, impairment of the carrying value of the generation assets serving Interim FERC Mitigation, and mark-to-market losses recognized on power sale agreements upon closing of the merger. Charges related to transmission projects and impairment of the carrying value of generation assets were recorded within Impairment charges in the Consolidated Statements of Operations. Mark-to-market losses on interim power sale agreements was recorded in Regulated electric operating revenues in the Consolidated Statements of Operations. Subsequent changes in fair value of interim power sale agreements over the life of the contracts and realized gains or losses on interim contract sales are also recorded within Regulated electric operating revenues. The ability to successfully defend future recovery of a portion of transmission projects in rates and any future changes to estimated transmission project costs could impact the amount not expected to be recovered.
	In conjunction with the merger, in November 2011, Duke Energy and Progress Energy each offered a voluntary severance plan (VSP) to certain eligible employees. VSP and other severance costs incurred were recorded primarily within Operation, maintenance and other in the Consolidated Statements of Operations. See Note 19 for further information related to employee severance expenses.
	Community support, charitable contributions and other reflect (i) the unconditional obligation to provide funding at a level comparable to historic practices over the next four years, and (ii) financial and legal advisory costs incurred upon the closing of the merger, retention and relocation costs paid to certain employees. These charges were recorded within Operation, maintenance and other in the Consolidated Statements of Operations.
	Impact of Merger
	The impact of Progress Energy on Duke Energy's revenues and net income attributable to Duke Energy in the Consolidated Statements of Operations for the year ended December 31, 2012 was an increase of $4,943 million and $368 million, respectively.
Chilean Operations
In December 2012, Duke 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. Purchase price allocation 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 $8 million of working capital. In connection with the acquisition, a $190 million six-month bridge loan and a $200 million revolving loan under a credit agreement were executed with a commercial bank. Both loans were fully collateralized with cash deposits, and therefore no net proceeds from the financings existed as of December 31, 2012. The $190 million bridge loan was classified in Current maturities of long-term debt and the related cash collateral deposit was classified as Current Assets on the Consolidated Balance Sheets as of December 31, 2012. The revolving loan is classified as Long-term Debt and the related cash collateral deposit is classified as Investments and Other Assets on the Consolidated Balance Sheets.
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 the cash collateral related to the six-month bridge loan was returned to Duke Energy. See Note 6 for additional discussion related to the bridge loan conversion.
Midwest Generation Exit
On February 17, 2014, Duke Energy Ohio announced that it had initiated a process to exit its nonregulated Midwest generation business. Considering a marketing period of several months and potential regulatory approvals, Duke Energy Ohio expects to dispose of the nonregulated Midwest generation business by early to mid-2015. In the first quarter of 2014, Duke Energy Ohio will reclassify approximately $3.5 billion carrying value of its Midwest generation business to assets held for sale and expects to record an estimated pretax impairment charge of $1 billion to $2 billion to reduce the carrying value to estimated sales proceeds less cost to sell.
Vermillion Generating Station
On January 12, 2012, after receiving approvals from the FERC and IURC on August 12, 2011 and December 28, 2011, respectively, Duke Energy Vermillion II, LLC (Duke Energy Vermillion), an indirect wholly owned subsidiary of Duke Energy Ohio, completed the sale of its ownership interest in Vermillion Generating Station (Vermillion) to Duke Energy Indiana and Wabash Valley Power Association (WVPA). Upon closing of the sale, Duke Energy Indiana held a 62.5 percent interest in Vermillion. Duke Energy Ohio received net proceeds of $82 million, of which $68 million was paid by Duke Energy Indiana. Following the transaction, Duke Energy Indiana retired Gallagher Units 1 and 3 effective February 1, 2012.
As Duke Energy Indiana is an affiliate of Duke Energy Vermillion, the transaction was accounted for as a transfer between entities under common control with no gain or loss recorded and did not have a significant impact to Duke Energy Ohio's or Duke Energy Indiana's results of operations. Proceeds received from Duke Energy Indiana are included in Net proceeds from the sales of other assets on Duke Energy Ohio's Consolidated Statements of Cash Flows. Cash paid to Duke Energy Ohio is included in Capital expenditures on Duke Energy Indiana's Consolidated Statements of Cash Flows. Duke Energy Ohio and Duke Energy Indiana recognized non-cash equity transfers of $28 million and $26 million, respectively, in their Consolidated Statements of Common Stockholder's Equity on the transaction representing the difference between cash exchanged and the net book value of Vermillion. These amounts are not reflected in Duke Energy's Consolidated Statements of Cash Flows or Consolidated Statements of Equity as the transaction is eliminated in consolidation.
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's and Duke Energy Ohio's Consolidated Statements of Cash Flows. The sale of the proportionate share of Vermillion to WVPA did not result in a significant gain or loss upon close of the transaction.
Wind Projects Joint Venture
In April 2012, Duke Energy executed a joint venture agreement with Sumitomo Corporation of America (SCOA). Under 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. 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. DS Cornerstone, LLC was initially consolidated with the sale to SCOA because of a guarantee provided by an indirect wholly owned subsidiary of Duke Energy. With the expiration of the guarantee in 2012, DS Cornerstone, LLC was deconsolidated.
Sales Of Other Assets
During 2012, Duke Energy received proceeds of $187 million from the sale of non-core business assets within the Commercial Power segment for which no material gain or loss was recognized.

Business_Segments

Business Segments	12 Months Ended
Business Segments	Dec. 31, 2013
Business Segments [Abstract]	'
Business Segments	'
	3. BUSINESS SEGMENTS
	Duke Energy evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income attributable to noncontrolling interests. Segment income, as discussed below, includes intercompany revenues and expenses that are eliminated in the Consolidated Financial Statements.
	Operating segments are determined based on information used by the chief operating decision maker in deciding how to allocate resources and evaluate the performance.
	Products and services are sold between affiliate companies and reportable segments of Duke Energy at cost. Segment assets as presented in the tables that follow exclude all intercompany assets.
	Duke Energy
	Duke Energy has the following reportable operating segments: Regulated Utilities, International Energy and Commercial Power.
	Regulated Utilities conducts operations primarily through Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Indiana, and the regulated transmission and distribution operations of Duke Energy Ohio. These electric and gas operations are subject to the rules and regulations of the FERC, NCUC, PSCSC, FPSC, PUCO, IURC, and KPSC. Substantially all of Regulated Utilities' operations are regulated and, accordingly, these operations qualify for regulatory accounting treatment.
	International Energy principally operates and manages power generation facilities and engages in sales and marketing of electric power, natural gas, and natural gas liquids outside the U.S. Its activities principally target power generation in Latin America. Additionally, International Energy owns a 25 percent interest in National Methanol Company (NMC), a large regional producer of Methyl tertiary butyl ether (MTBE) located in Saudi Arabia. The investment in NMC is accounted for under the equity method of accounting.
	Commercial Power owns, operates and manages power plants and engages in the wholesale marketing and procurement of electric power, fuel and emission allowances related to these plants as well as other contractual positions. Commercial Power's generation operations consist primarily of Duke Energy Ohio's coal-fired and gas-fired nonregulated generation assets located in the Midwest region of the U.S. and wind and solar generation located throughout the U.S. The asset portfolio has a diversified fuel mix with baseload and mid-merit coal-fired units as well as combined cycle and peaking natural gas-fired units. In addition, Commercial Power operates and develops transmission projects.
	The remainder of Duke Energy's operations is presented as Other. While it is not an operating segment, Other primarily includes unallocated corporate interest expense, certain unallocated corporate costs, Bison Insurance Company Limited (Bison), Duke Energy's wholly owned, captive insurance subsidiary, and contributions to the Duke Energy Foundation. On December 31, 2013, Duke Energy sold its interest in DukeNet Communications Holdings, LLC (DukeNet) to Time Warner Cable, Inc. See Note 12 for further information.
			Year Ended December 31, 2013
												Total
			Regulated			International			Commercial			Reportable
	(in millions)		Utilities			Energy			Power			Segments			Other			Eliminations			Total
	Unaffiliated revenues^(a)(b)(c)		$	20,871		$	1,546		$	2,106		$	24,523		$	75		$	―		$	24,598
	Intersegment revenues			39			―			39			78			88			-166			―
		Total revenues	$	20,910		$	1,546		$	2,145		$	24,601		$	163		$	-166		$	24,598
	Interest expense		$	986		$	86		$	64		$	1,136		$	417		$	-7		$	1,546
	Depreciation and amortization			2,323			100			250			2,673			135			―			2,808
	Equity in earnings of unconsolidated affiliates			-1			110			7			116			6			―			122
	Income tax expense (benefit)			1,522			166			-104			1,584			-323			―			1,261
	Segment income^{(a)(b)(c)(d)(e)(f)(g)}			2,504			408			-3			2,909			-261			―			2,648
	Add back noncontrolling interest component																					11
	Income from discontinued operations, net of tax																					17
	Net income																				$	2,676
	Capital investments expenditures and acquisitions		$	5,049		$	67		$	268		$	5,384		$	223		$	―		$	5,607
	Segment assets			99,884			4,998			6,955			111,837			2,754			188			114,779

	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts Regulated Utilities. 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 Regulated Utilities. See Note 4 for additional information about the revised customer rates.
	(c)	In September 2013, Duke Energy Carolinas implemented revised rates approved by the NCUC and the PSCSC. This increase impacts Regulated Utilities. See Note 4 for additional information about the revised customer rates.
	(d)	Regulated Utilities recorded charges related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information about the Crystal River Unit 3 charges.
	(e)	Regulated Utilities recorded an impairment charge related to Duke Energy Progress' Shearon Harris Nuclear Station (Harris) site. Regulated Utilities also recorded an impairment charge related to Duke Energy Florida's proposed nuclear plant in Levy County, Florida (Levy) site. 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. See Notes 2 and 25 for additional information about the merger and related costs.
	(g)	Other includes gain from the sale of Duke Energy's ownership interest in DukeNet. See Note 12 for additional information on the sale of DukeNet.

			Year Ended December 31, 2012
												Total
			Regulated			International			Commercial			Reportable
	(in millions)		Utilities			Energy			Power			Segments			Other			Eliminations			Total
	Unaffiliated revenues		$	16,042		$	1,549		$	2,020		$	19,611		$	13		$	―		$	19,624
	Intersegment revenues			38			―			58			96			47			-143			―
		Total revenues	$	16,080		$	1,549		$	2,078		$	19,707		$	60		$	-143		$	19,624
	Interest expense		$	806		$	77		$	63		$	946		$	296		$	―		$	1,242
	Depreciation and amortization			1,827			99			228			2,154			135			―			2,289
	Equity in earnings of unconsolidated affiliates			-5			134			14			143			5			―			148
	Income tax expense (benefit)			942			149			-8			1,083			-378			―			705
	Segment income^(a)(b)			1,744			439			87			2,270			-538			―			1,732
	Add back noncontrolling interest component																					14
	Income from discontinued operations, net of tax																					36
	Net income																				$	1,782
	Capital investments expenditures and acquisitions		$	4,220		$	551		$	1,038		$	5,809		$	149		$	―		$	5,958
	Segment assets			98,162			5,406			6,992			110,560			3,126			170			113,856

	(a)	Regulated Utilities recorded charges related to Duke Energy Indiana's IGCC project. See Note 4 for additional information about these charges. Regulated Utilities 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 19 for additional information about these expenses.
	(b)	Other includes after-tax costs to achieve the merger with Progress Energy. See Notes 2 and 25 for additional information about the merger and related costs.

			Year Ended December 31, 2011

			Regulated			International			Commercial Power			Total Reportable
	(in millions)		Utilities			Energy			Energy			Segments^(a)		Other			Eliminations			Total
	Unaffiliated revenues		$	10,586		$	1,467		$	2,480		$	14,533	$	-4		$	―		$	14,529
	Intersegment revenues			33			―			11			44		48			-92			―
	Total revenues	$	10,619		$	1,467		$	2,491		$	14,577	$	44		$	-92		$	14,529
Interest expense		$	568		$	47		$	87		$	702	$	157		$	―		$	859
Depreciation and amortization			1,383			90			230			1,703		103			―			1,806
Equity in earnings of unconsolidated affiliates			―			145			6			151		9			―			160
Income tax expense (benefit)			674			196			-2			868		-116			―			752
Segment income^(a)(b)			1,181			466			134			1,781		-76			―			1,705
Add back noncontrolling interest component																				8
Income from discontinued operations, net of tax																				1
Net income																			$	1,714
Capital investments expenditures and acquisitions		$	3,717		$	114		$	492		$	4,323	$	141		$	―		$	4,464
Segment assets			47,977			4,539			6,939			59,455		2,961			110			62,526

(a)	Regulated Utilities recorded charges related to Duke Energy Indiana's IGCC project. See Note 4 for additional information about these charges.
(b)	Commercial Power recorded charges to write-down the carrying value of certain emission allowances. See Note 11 for additional information about these charges.

The following table includes information by geographic segment.

(in millions)		U.S.			Latin America^(a)			Consolidated
2013
Consolidated revenues		$	23,053		$	1,545		$	24,598
Consolidated long-lived assets			78,581			2,781			81,362
2012
Consolidated revenues		$	18,078		$	1,546		$	19,624
Consolidated long-lived assets			79,144			2,467			81,611
2011
Consolidated revenues		$	13,062		$	1,467		$	14,529
Consolidated long-lived assets			45,920			2,612			48,532

(a)	Change in amounts of long-lived assets in Latin America includes foreign currency translation adjustments on property, plant and equipment and other long-lived asset balances.

Duke Energy Ohio
Duke Energy Ohio has two reportable operating segments, Regulated Utilities and Commercial Power.
Regulated Utilities transmits and distributes electricity in portions of Ohio and generates, distributes and sells electricity in portions of Kentucky. Regulated Utilities also transports and sells natural gas in portions of Ohio and northern Kentucky. It conducts operations primarily through Duke Energy Ohio and its wholly owned subsidiary, Duke Energy Kentucky.
Commercial Power owns, operates and manages power plants and engages in the wholesale marketing and procurement of electric power, fuel and emission allowances related to these plants, as well as other contractual positions.
The remainder of Duke Energy Ohio's operations is presented as Other. While it is not considered an operating segment, Other primarily includes certain governance costs allocated by its parent, Duke Energy. See Note 13 for additional information. All of Duke Energy Ohio's revenues are generated domestically and its long-lived assets are all in the U.S.
		Year Ended December 31, 2013
(in millions)		Regulated Utilities			Commercial Power		Total Reportable Segments			Other			Eliminations			Total
Unaffiliated revenues^(a)		$	1,765		$	1,480	$	3,245		$	―		$	―		$	3,245
Intersegment revenues			―			32		32			―			-32			―
	Total revenues	$	1,765		$	1,512	$	3,277		$	―		$	-32		$	3,245
Interest expense		$	74		$	4	$	78		$	―		$	―		$	78
Depreciation and amortization			200			154		354			―			―			354
Income tax expense (benefit)			91			-14		77			-2			―			75
Segment income/consolidated net income			151			-20		131			-29			―			102
Capital expenditures			375			58		433			―			―			433
Segment assets			6,649			4,170		10,819			99			-155			10,763

(a)	Duke Energy Ohio earned approximately 37 percent of its consolidated operating revenues from PJM Interconnection, LLC (PJM) in 2013, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.

		Year Ended December 31, 2012
(in millions)		Regulated Utilities			Commercial Power		Total Reportable Segments			Other			Eliminations			Total
Unaffiliated revenues^(a)		$	1,745		$	1,407	$	3,152		$	―		$	―		$	3,152
Intersegment revenues			1			51		52			―			-52			―
	Total revenues	$	1,746		$	1,458	$	3,204		$	―		$	-52		$	3,152
Interest expense		$	61		$	28	$	89		$	―		$	―		$	89
Depreciation and amortization			179			159		338			―			―			338
Income tax expense (benefit)			91			25		116			-18			―			98
Segment income/consolidated net income			159			50		209			-34			―			175
Capital expenditures			427			87		514			―			―			514
Segment assets			6,434			4,175		10,609			117			-166			10,560

(a)	Duke Energy Ohio earned approximately 36 percent of its consolidated operating revenues from PJM in 2012, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.

		Year Ended December 31, 2011
(in millions)		Regulated Utilities			Commercial Power		Total Reportable Segments			Other			Eliminations			Total
Unaffiliated revenues^(a)		$	1,474		$	1,707	$	3,181		$	―		$	―		$	3,181
Intersegment revenues			―			4		4			―			-4			―
	Total revenues	$	1,474		$	1,711	$	3,185		$	―		$	-4		$	3,181
Interest expense		$	68		$	36	$	104		$	―		$	―		$	104
Depreciation and amortization			168			167		335			―			―			335
Income tax expense (benefit)			98			6		104			-8			―			96
Segment income/consolidated net income^(b)			133			78		211			-17			―			194
Capital expenditures			375			124		499			―			―			499
Segment assets			6,293			4,740		11,033			259			-353			10,939

(a)	Duke Energy Ohio earned approximately 24 percent of its consolidated operating revenues from PJM in 2011, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.
(b)	Commercial Power recorded charges during the year ended December 31, 2011, to write-down the carrying value of certain emission allowances. See Note 11 for additional information.

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, Regulated Utility, 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 certain unallocated corporate costs. Other for Progress Energy also includes interest expense on corporate debt instruments of $300 million, $304 million and $324 million for the years ended December 31, 2013, 2012 and 2011. The following table summarizes the net loss for Other for each of these entities.

		Years Ended December 31,
(in millions)		2013				2012		2011
Duke Energy Carolinas		$	-97		$	-169		$	-46
Progress Energy			-241			-379			-273
Duke Energy Progress			-46			-139			-18
Duke Energy Florida			-24			-58			-16
Duke Energy Indiana			-16			-27			-12

Duke Energy Progress earned approximately 10 percent of its consolidated operating revenues from North Carolina Electric Membership Corporation (NCEMC) in 2013. These revenues relate to wholesale contracts and transmission revenues. The respective Regulated Utility and Regulated Utilities operating segments own substantially all of Duke Energy Carolinas', Progress Energy's, Duke Energy Progress', Duke Energy Florida's and Duke Energy Indiana's assets at December 31, 2013, 2012 and 2011.

Regulatory_Matters

Regulatory Matters	12 Months Ended
Regulatory Matters	Dec. 31, 2013
Regulatory Matters [Abstract]	'
Regulatory Matters	'
	4. REGULATORY MATTERS
	Regulatory Assets and Liabilities
	The Duke Energy Registrants record regulatory assets and liabilities that result from the ratemaking process. See Note 1 for further information.
	The following tables present the regulatory assets and liabilities recorded on the Consolidated Balance Sheets.

			31-Dec-13
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Regulatory Assets
	Accrued pension and OPEB		$	1,723		$	347		$	750		$	269		$	438		$	120		$	219
	Retired generation facilities			1,748			68			1,619			241			1,378			―			61
	Debt fair value adjustment			1,338			―			―			―			―			―			―
	Asset retirement obligations			1,608			123			786			389			397			―			―
	Net regulatory asset related to income taxes			1,115			555			331			113			218			72			157
	Hedge costs and other deferrals			450			98			318			165			153			5			29
	Demand side management (DSM)/Energy efficiency (EE)			371			140			152			140			12			79			―
	Vacation accrual			210			82			55			50			―			7			13
	Deferred fuel			94			―			37			6			31			14			43
	Nuclear deferral			262			40			222			77			145			―			―
	Post-in-service carrying costs and deferred operating expenses			459			150			137			19			118			21			151
	Gasification services agreement buyout			75			―			―			―			―			―			75
	Transmission expansion obligation			70			―			―			―			―			74			―
	Manufactured gas plant (MGP)			90			―			―			―			―			90			―
	Other			473			219			101			42			60			46			87
	Total regulatory assets			10,086			1,822			4,508			1,511			2,950			528			835
	Less: current portion			895			295			353			127			221			57			118
	Total non-current regulatory assets		$	9,191		$	1,527		$	4,155		$	1,384		$	2,729		$	471		$	717


			31-Dec-13
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Regulatory Liabilities
	Costs of removal		$	5,308		$	2,423		$	2,008		$	1,637		$	371		$	241		$	645
	Amounts to be refunded to customers			151			―			120			―			120			―			31
	Storm reserve			145			20			125			―			125			―			―
	Accrued pension and OPEB			138			―			―			―			―			21			77
	Deferred fuel			177			45			132			―			132			―			―
	Other			346			153			114			99			14			27			45
	Total regulatory liabilities			6,265			2,641			2,499			1,736			762			289			798
	Less: current portion			316			65			207			63			144			27			16
	Total non-current regulatory liabilities		$	5,949		$	2,576		$	2,292		$	1,673		$	618		$	262		$	782


			31-Dec-12
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Regulatory Assets
	Accrued pension and OPEB		$	3,306		$	602			1,650		$	769		$	754		$	225		$	325
	Retired generation facilities			1,781			―			1,720			128			1,592			―			61
	Debt fair value adjustment			1,472			―			―			―			―			―			―
	Asset retirement obligations			1,461			48			713			372			341			―			―
	Net regulatory asset related to income taxes			1,373			731			401			175			226			82			158
	Hedge costs and other deferrals			710			88			550			240			310			9			63
	DSM/EE			322			107			121			121			―			94			―
	Vacation accrual			245			85		$	65			65			―			7			13
	Deferred fuel			162			―			109			―			109			1			52
	Nuclear deferral			142			―			142			―			142			―			―
	Post-in-service carrying costs and deferred operating expenses			122			27			―			―			―			19			76
	Gasification services agreement buyout			95			―			―			―			―			―			95
	Transmission expansion obligation			72			―			―			―			―			72			―
	MGP			77			―			―			―			―			77			―
	Other			401			260			77			52			26			39			93
	Total regulatory assets			11,741			1,948			5,548			1,922			3,500			625			936
	Less: current portion			737			221			256			77			179			46			126
	Total non-current regulatory assets		$	11,004		$	1,727		$	5,292		$	1,845		$	3,321		$	579		$	810


		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory Liabilities
Costs of removal		$	4,827		$	1,928		$	2,048		$	1,503		$	401		$	236		$	624
Amounts to be refunded to customers			290			―			259			―			259			―			31
Storm reserve			125			―			125			―			125			―			―
Accrued pension and OPEB			103			―			―			―			―			18			68
Deferred fuel			55			45			10			10			―			―			―
Other			340			207			55			35			20			39			29
Total regulatory liabilities			5,740			2,180			2,497			1,548			805			293			752
Less: current portion			156			78			28			10			18			39			11
Total non-current regulatory liabilities		$	5,584		$	2,102		$	2,469		$	1,538		$	787		$	254		$	741


Descriptions of regulatory assets and liabilities, summarized in the tables above, as well as their recovery and amortization periods follow. Items are excluded from rate base unless otherwise noted.
Accrued pension and OPEB. Accrued pension and OPEB represent regulatory assets and liabilities related to each of the Duke Energy Registrants' respective shares of unrecognized actuarial gains and losses, unrecognized prior service cost, and unrecognized transition obligation attributable to Duke Energy's pension plans and OPEB plans. The regulatory asset or liability is amortized with the recognition of actuarial gains and losses, prior service cost, and transition obligations to net periodic benefit costs for pension and OPEB plans. See Note 21 for additional detail.
Retired generation facilities. Duke Energy Florida earns a reduced return on a substantial portion of the amount of regulatory asset associated with the retirement of Crystal River Unit 3 not included in rate base and a full return on a portion of the retired plant currently recovered in rates. Once included in base rates the amount will be amortized over 20 years. Duke Energy Carolinas and Duke Energy Progress earn a return on the outstanding balance with recovery periods ranging from five to 10 years. Duke Energy Indiana earns a return on the outstanding balances and the costs are included in rate base.
Asset retirement obligations. Represents future removal costs associated with asset retirement obligations for nuclear facilities. No return is earned on these balances. The recovery period runs through the decommissioning period of each nuclear unit, the latest of which is estimated to be 2097. See Note 9 for additional information.
Net regulatory asset related to income taxes. Regulatory assets principally associated with the depreciation and recovery of AFUDC equity. Amounts have no impact on rate base as regulatory assets are offset by deferred tax liabilities. The recovery period is over the life of the associated assets.
Hedge costs and other deferrals. Amounts relate to unrealized gains and losses on derivatives recorded as a regulatory asset or liability, respectively, until the contracts are settled. The recovery period varies for these costs, and currently extends to 2027.
DSM/EE. The recovery period varies for these costs, with some currently unknown. Duke Energy Carolinas, Duke Energy Progress, and Duke Energy Florida are required to pay interest on the outstanding liability balance. Duke Energy Progress and Duke Energy Florida collect a return on the outstanding asset balance. Duke Energy Carolinas collects a return on the outstanding balance in South Carolina.
Vacation accrual. Generally recovered within one year.
Deferred fuel. Deferred fuel costs represent certain energy costs that are recoverable or refundable as approved by the applicable regulatory body. Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana earn a return on under-recovered costs. Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana pay interest on over-recovered costs. Duke Energy Carolinas and Duke Energy Progress pay interest on over-recovered costs in North Carolina. Recovery period is generally over one year. Duke Energy Florida amount includes capacity costs.
Nuclear deferral. Includes (i) amounts related to levelizing nuclear plant outage costs at Duke Energy Carolinas in North Carolina and South Carolina, and Duke Energy Progress in North Carolina, which allows for the recognition of nuclear outage expenses over the refueling cycle rather than when the outage occurs, resulting in the deferral of operations and maintenance costs associated with refueling and (ii) certain deferred preconstruction and carrying costs at Duke Energy Florida as approved by the FPSC associated with Levy, expected to be recovered in revenues by the end of 2017.
Post-in-service carrying costs and deferred operating expenses. Represents deferred depreciation and operating expenses as well as carrying costs on the portion of capital expenditures placed in service but not yet reflected in retail rates as plant in service. Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana earn a return on the outstanding balance. Duke Energy Ohio amounts are included in rate base. For Duke Energy Indiana, some amounts are included in rate base. Recovery is over various lives, and the latest recovery period is 2067.
Gasification services agreement buyout. The IURC authorized Duke Energy Indiana to recover costs incurred to buyout a gasification services agreement, including carrying costs through 2018.
Transmission expansion obligation. Represents transmission expansion obligations related to Duke Energy Ohio's withdrawal from Midcontinent Independent System Operator, Inc. (MISO).
MGP. Represents remediation costs for former MGP sites. In November 2013, the PUCO approved recovery of these costs through 2018. Duke Energy Ohio does not earn a return on these costs. See Note 5, Commitments and Contingencies, for additional information.
Debt fair value adjustment. Purchase accounting adjustment to restate the carrying value of Progress Energy debt to fair value. Amount is amortized over the life of the related debt.
Costs of removal. Represents funds received from customers to cover the future removal of property, plant and equipment from retired or abandoned sites as property is retired. Also includes unrealized gains on NDTF investments.
Amounts to be refunded to customers. Represents required refunds to retail customers by the applicable regulatory body. The refund period is through 2016 for Duke Energy Florida and through 2017 for Duke Energy Indiana.
Storm reserve. Duke Energy Carolinas and Duke Energy Florida are allowed to petition the PSCSC and FPSC, respectively, to seek recovery of named storms. Funds are used to offset future incurred costs.
Restrictions on the Ability of Certain Subsidiaries to Make Dividends, Advances and Loans to Duke Energy
As a condition to the approval of merger transactions, the NCUC, PSCSC, PUCO, KPSC, and IURC imposed conditions on the ability of Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio, Duke Energy Kentucky and Duke Energy Indiana to transfer funds to Duke Energy through loans or advances, as well as restricted amounts available to pay dividends to Duke Energy. Certain subsidiaries may transfer funds to the parent by obtaining approval of the respective state regulatory commissions. These conditions imposed restrictions on the ability of the public utility subsidiaries to pay cash dividends as discussed below.
Duke Energy Progress and Duke Energy Florida also have restrictions imposed by their first mortgage bond indentures and Articles of Incorporation which, in certain circumstances, limited their ability to make cash dividends or distributions on common stock. Amounts restricted as a result of these provisions were not material at December 31, 2013.
Additionally, certain other subsidiaries of Duke Energy have restrictions on their ability to dividend, loan or advance funds to Duke Energy due to specific legal or regulatory restrictions, including, but not limited to, minimum working capital and tangible net worth requirements.
Duke Energy Carolinas
Duke Energy Carolinas must limit cumulative distributions subsequent to mergers to (i) the amount of retained earnings on the day prior to the closing of the mergers, plus (ii) any future earnings recorded.
Duke Energy Progress
Duke Energy Progress must limit cumulative distributions subsequent to the merger between Duke Energy and Progress Energy to (i) the amount of retained earnings on the day prior to the closing of the merger, plus (ii) any future earnings recorded.
Duke Energy Ohio
Duke Energy Ohio will not declare and pay dividends out of capital or unearned surplus without the prior authorization of the PUCO. Duke Energy Ohio received FERC and PUCO approval to pay dividends from its equity accounts that are reflective of the amount that it would have in its retained earnings account had push-down accounting for the Cinergy Corp. (Cinergy) merger not been applied to Duke Energy Ohio's balance sheet. The conditions include a commitment from Duke Energy Ohio that equity, adjusted to remove the impacts of push-down accounting, will not fall below 30 percent of total capital.
Duke Energy Kentucky is required to pay dividends solely out of retained earnings and to maintain a minimum of 35 percent equity in its capital structure.
Duke Energy Indiana
Duke Energy Indiana must limit cumulative distributions subsequent to the merger between Duke Energy and Cinergy to (i) the amount of retained earnings on the day prior to the closing of the merger, plus (ii) any future earnings recorded. In addition, Duke Energy Indiana will not declare and pay dividends out of capital or unearned surplus without prior authorization of the IURC.
The restrictions discussed above were less than 25 percent of Duke Energy's net assets at December 31, 2013.
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 (excluding Ohio and Indiana), 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 agreed to a three-year step-in rate increase, with the first two years providing for $204 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. On December 11, 2013, Duke Energy Carolinas and Duke Energy Progress, along with the Public Staff, filed a Motion to Consolidate this appeal with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress. Both the NCAG and NC WARN filed responses with the North Carolina Supreme Court (NCSC) contesting consolidation. All parties are awaiting a ruling from the NCSC. 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 October 23, 2013, the NCUC reaffirmed the rate of return approved in the January 27, 2012 settlement agreement, in response to an appeal by the NCAG. On November 21, 2013, the NCAG appealed the reaffirmed order. On December 11, 2013, Duke Energy Carolinas and Duke Energy Progress, along with the Public Staff, filed a Motion to Consolidate this appeal with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress. Both the NCAG and NC WARN filed responses with the NCSC contesting consolidation. All parties are awaiting a ruling from the NCSC. Duke Energy Carolinas cannot predict the outcome of this matter.
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 did not commit Duke Energy Carolinas to build nuclear units. Through several separate orders, the NCUC and PSCSC 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 $382 million, including AFUDC through December 31, 2013. This amount is included in Net property, plant and equipment on Duke Energy Carolinas' 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 November 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.
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 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 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 shareholder 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. NC WARN also appealed various matters in the settlement. On December 11, 2013, Duke Energy Carolinas and Duke Energy Progress, along with the Public Staff, filed a Motion to Consolidate this appeal with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress. Both the NCAG and NC WARN filed responses with the NCSC contesting consolidation. All parties are awaiting a ruling from the NCSC. Duke Energy Progress cannot predict the outcome of this matter.
L.V. Sutton Combined Cycle Facility
Duke Energy Progress completed construction of a 625 MW combined cycle natural gas-fired generating facility at its existing Sutton Steam Station in New Hanover County, North Carolina. Sutton began commercial operations in the fourth quarter of 2013.
Harris 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 and January 30, 2014, respectively, the NCUC and PSCSC approved the deferral of the respective retail portion of the COL costs. Approximately $47 million is recorded in Regulatory assets on Duke Energy Progress' Consolidated Balance Sheets at December 31, 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 Duke Energy Progress wholesale power customers that 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 an action with respect to the justness and reasonableness of the proposed rate changes. 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 it did not have a high degree of confidence the 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. In December 2013, Duke Energy Florida filed an updated site-specific decommissioning study and plan with the NRC and FPSC. The study resulted in a decommissioning cost estimate of $1,180 million, including amounts applicable to joint owners, under the safe storage (SAFSTOR) option. Duke Energy Florida's decommissioning study assumes Crystal River Unit 3 will be in SAFSTOR configuration, requiring limited staffing to monitor plant conditions, until the eventual dismantling and decontamination activities occur in 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.
Duke Energy Florida maintains insurance coverage through Nuclear Electric Insurance Limited's (NEIL) accidental property damage program on an actual cash value basis. The NEIL coverage generally does not include property damage to or resulting from the containment structure. However, 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 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; the uprate project; and the components of the regulatory asset to be recovered in rates beginning no later than 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 in accordance with 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, payroll taxes, property taxes, and depreciation associated with Crystal River Unit 3 were deferred to a regulatory asset. Duke Energy Florida deferred $134 million of these costs to Regulatory assets through December 31, 2013. 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. 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 Statements of Operations and Comprehensive Income.
Duke Energy Florida is allowed to accelerate cash recovery of approximately $130 million of the Crystal River Unit 3 regulatory asset 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. 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 December 31, 2013, Duke Energy Florida deferred $1,310 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 $323 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.

		31-Dec-13
									Remaining Amount to be Refunded
(in millions)		Total			Refunded to date			2014			2015			2016
2012 Settlement refund^(a)		$	288		$	129		$	139		$	10		$	10
Retirement decision refund			100			-			-			40			60
NEIL proceeds			490			326			164			-			-
Total customer refunds			878			455			303			50			70
Accelerated regulatory asset recovery			-130			-			-37			-37			-56
Net customer refunds		$	748		$	455		$	266		$	13		$	14

(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 joint owner and extended a settlement offer to the other joint owner related to all Crystal River Unit 3 matters. Duke Energy Florida recorded a charge of $45 million in the fourth quarter of 2012 related to the December 2012 settlement and settlement offer. In January 2014, Duke Energy Florida reached an agreement in principle with the remaining joint owner regarding resolution of matters associated with Crystal River Unit 3 based on condition precedents that must be met in order to carry out the agreement. Duke Energy Florida recorded a charge of $57 million in the fourth quarter of 2013 related to the January 2014 agreement. The significant majority of these amounts were included in Operations, maintenance and other on the Statements of Operations and Comprehensive Income.
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, with exceptions for base rate increases for the recovery of the Crystal River Unit 3 regulatory asset beginning no later than 2017 and base rate increases for new generation through 2018, per the provisions of the 2013 Settlement. 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. 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 monthly earnings surveillance report, it may petition the FPSC to amend its base rates during the term of the 2013 Settlement.
Duke Energy Florida is refunding $288 million to retail customers through its fuel clause, as required by the 2012 Settlement.
Levy
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.
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 including 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. The consumer parties agree to not oppose Duke Energy Florida continuing to pursue a COL for Levy.
On January 28, 2014, Duke Energy Florida terminated the EPC. Duke Energy Florida may be required to pay for work performed under the EPC and to bring existing work to an orderly conclusion, including but not limited to, costs to demobilize and cancel certain equipment and material orders placed. Duke Energy Florida is allowed to recover reasonable and prudent EPC cancellation costs from its retail customers. 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 the 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 December 31, 2013, Duke Energy Florida has a net uncollected investment in Levy of approximately $264 million, including AFUDC. Of this amount, $50 million is included in Regulatory assets, $117 million related to land and the COL is included in Net, property, plant and equipment, and $97 million is included in Regulatory assets within Current Assets on the Balance Sheets.
Crystal River 1 and 2 Coal Units
Duke Energy Florida has evaluated Crystal River 1 and 2 coal units for retirement in order to comply with certain environmental regulations. Based on this evaluation, those units will likely be retired by 2018. Once 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. On December 31, 2013 Duke Energy Florida filed a petition with the FPSC to allow for the recovery of prudently incurred costs to comply with the Mercury and Air Toxics Standard through the Environmental Cost Recovery Clause.
New Generation
Duke Energy Florida currently projects a significant need for additional generation to offset the impact of retirement of Crystal River Unit 3 as well as the 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. Duke Energy Florida is currently reviewing bids received on December 9, 2013.
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 reduction in amortization expense of $114 million, $178 million, and $250 million for the years ended December 31, 2013, 2012, and 2011 respectively. Duke Energy Florida had no cost of removal reserves eligible for amortization to income remaining at December 31, 2013
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. On February 13, 2014, the PUCO denied Duke Energy Ohio's request.
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.
On November 13, 2013, the PUCO issued an order approving the Gas Settlement and allowing for the recovery of $56 million of MGP costs, excluding carrying costs, to be recovered over a five-year period beginning in 2014. On February 19, 2014, the PUCO denied intervening consumer groups' motion to stay implementation of its order, or, in the alternative, to implement the MGP rider subject to refund. Intervening groups have provided notice of their intent to appeal the PUCO's decision to the Ohio Supreme Court. Duke Energy Ohio cannot predict the outcome of this matter.
Generation Asset Transfer
On April 2, 2012 and amended on June 22, 2012, Duke Energy Ohio and various affiliated entities filed an Application for Authorization for Disposition of Jurisdictional Facilities with FERC. The application seeks to transfer, from Duke Energy Ohio's rate-regulated Ohio utility company, the legacy coal-fired and combustion gas turbine assets to a nonregulated affiliate, consistent with the ESP stipulation approved by the PUCO on November 22, 2011. The application outlines a potential additional step in the reorganization that would result in a transfer of all of Duke Energy Ohio's Commercial Power business to an indirect wholly owned subsidiary of Duke Energy. The process of determining the optimal corporate structure is an ongoing evaluation of factors, such as tax considerations, that may change between now and the transfer date. In conjunction with the transfer, Duke Energy Ohio's capital structure will be restructured to reflect appropriate debt and equity ratios for its regulated operations. The transfer could instead be accomplished within a wholly owned nonregulated subsidiary of Duke Energy Ohio depending on final tax structuring analysis. The FERC approved the application on September 5, 2012. Duke Energy Ohio agreed to transfer the legacy coal-fired and combustion gas turbine assets on or before December 31, 2014.
Regional Transmission Organization (RTO) Realignment
Duke Energy Ohio including Duke Energy Kentucky, transferred control of its transmission assets from MISO to PJM, effective December 31, 2011.
On December 22, 2010, the KPSC approved Duke Energy Kentucky's request to effect the RTO realignment, subject to 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 MISO Transmission Expansion Project (MTEP) costs, including but not limited to Multi-Value Project (MVP) costs, directly or indirectly charged to Duke Energy Ohio retail customers. Duke Energy Ohio will not 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.
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 Consolidated Balance Sheets.
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 December 31, 2013^(a)
Duke Energy Ohio		$	97		$	2		$	-4		$	95

(a)	As of December 31, 2013, $74 million is recorded as a Regulatory asset on Duke Energy Ohio's Consolidated Balance Sheets.

MVP. MISO approved 17 MVP proposals prior to Duke Energy Ohio's exit from MISO on December 31, 2011. Construction of these projects is expected to continue through 2020. Costs of these projects, including operating and maintenance costs, property and income taxes, depreciation and an allowed return, are allocated and billed to MISO transmission owners.
On December 29, 2011, MISO filed a tariff with the FERC providing for the allocation of MVP costs to a withdrawing owner based on monthly energy usage. The FERC set for hearing (i) whether MISO's proposed cost allocation methodology to transmission owners who withdrew from MISO prior to January 1, 2012 is consistent with the tariff at the time of their withdrawal from MISO, and, (ii) if not, what amount of, and methodology for calculating any MVP cost responsibility should be. On July 16, 2013, a FERC Administrative Law Judge (ALJ) issued an initial decision. 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 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. Duke Energy Ohio cannot predict the outcome of these proceedings.
In 2012, MISO estimated Duke Energy Ohio's MVP obligation over the period from 2012 to 2071 at $2.7 billion, on an undiscounted basis. The estimated obligation is subject to great uncertainty including the ultimate cost of the projects, the annual costs of O&M, taxes and return over the project lives and the allocation to Duke Energy Ohio.
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., Sierra Club, Inc., Save the Valley, Inc., and Valley Watch, Inc., 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. As a result, the projected cost estimate increased throughout construction of the project and various revised estimates were filed with the IURC. In October 2012, Duke Energy Indiana revised its latest projected cost estimate to $3.15 billion (excluding AFUDC).
On December 27, 2012, the IURC approved a settlement agreement (2012 Edwardsport settlement) 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 2012 Edwardsport settlement 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 pretax charges of approximately $897 million related to the Edwardsport project, including the settlement agreement discussed above. Of this amount, pretax impairment and other charges of $631 million were recorded during the year ended December 31, 2012. These charges were recorded in Impairment charges and Operations, maintenance and other on Duke Energy Indiana's Consolidated Statements of Operations and Comprehensive Income.
The Joint Intervenors appealed the IURC order approving the 2012 Edwardsport settlement 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. Costs for the Edwardsport IGCC plant are recovered from retail electric customers via a tracking mechanism, the IGCC Rider.
Other Regulatory Matters
Merger Appeals
On January 9, 2013, the City of Orangeburg and NC WARN appealed the NCUC's approval of the merger between Duke Energy and Progress Energy. On April 29, 2013, the NCUC granted Duke Energy's motion to dismiss certain exceptions contained in NC WARN's appeal. On November 6, 2013, the North Carolina Court of Appeals heard oral arguments on the appeals. A decision from the North Carolina Court of Appeals is pending.
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. 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 in 2014. On August 8, 2012, FERC granted certain intervenors' request for rehearing for further consideration.
Following the closing of the merger, outside counsel reviewed Duke Energy's mitigation plan and discovered a technical error in the calculations. On December 6, 2013, Duke Energy submitted a filing with the FERC disclosing the error and arguing that no additional mitigation is necessary. On February 4, 2014, The City of New Bern, North Carolina filed comments to Duke Energy's filing. Duke Energy's response to New Bern was filed on February 19, 2014. 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 IRPs filed by the Subsidiary Registrants in 2013, 2012 and 2011 included planning assumptions to potentially retire certain coal-fired generating facilities in South Carolina, Florida, Indiana and Ohio earlier than their current estimated useful lives. The facilities do not have the requisite emission control equipment, primarily to meet 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 Consolidated Balance Sheets.

		31-Dec-13
			Duke Energy		Duke Energy Carolinas^(b)			Progress Energy^(c)			Duke Energy Florida^(c)			Duke Energy Ohio^(d)			Duke Energy Indiana^(e)
Capacity (in MW)			2,447			200			873			873			706			668
Remaining net book value (in millions)^(a)		$	260		$	14		$	113		$	113		$	10		$	123

(a)	Included in Property, plant and equipment, net as of December 31, 2013, on the Consolidated Balance Sheets.
(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 Crystal River Units 1 and 2.
(d)	Includes Beckjord Units 4 through 6 and Miami Fort Unit 6. 150 MW Beckjord Station Unit 4 was retired on February 17, 2014. Beckjord units have no remaining book value.
(e)	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	12 Months Ended
Commitments and Contingencies	Dec. 31, 2013
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	5. COMMITMENTS AND CONTINGENCIES
	General Insurance
	The Duke Energy Registrants have insurance and reinsurance coverage either directly or through indemnification from Duke Energy's captive insurance company, Bison, and its affiliates, consistent with companies engaged in similar commercial operations with similar type properties. The Duke Energy Registrants' coverage includes (i) commercial general liability coverage for liabilities arising to third parties for bodily injury and property damage; (ii) workers' compensation; (iii) automobile liability coverage; and (iv) property coverage for all real and personal property damage. Real and personal property damage coverage excludes electric transmission and distribution lines, but includes damages arising from boiler and machinery breakdowns, earthquakes, flood damage and extra expense, but not outage or replacement power coverage. All coverage is subject to certain deductibles or retentions, sublimits, exclusions, terms and conditions common for companies with similar types of operations.
	The Duke Energy Registrants self-insure their electric transmission and distribution lines against loss due to storm damage and other natural disasters. As discussed further in Note 4, Duke Energy Florida maintains a storm damage reserve and has a regulatory mechanism to recover the cost of named storms on an expedited basis.
	The cost of the Duke Energy Registrants' coverage can fluctuate year to year reflecting claims history and conditions of the insurance and reinsurance markets.
	In the event of a loss, terms and amounts of insurance and reinsurance available might not be adequate to cover claims and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered by other sources, could have a material effect on the Duke Energy Registrants' results of operations, cash flows or financial position. Each company is responsible to the extent losses may exceed limits of the coverage available.
	Nuclear Insurance
	Duke Energy Carolinas owns and operates the McGuire Nuclear Station (McGuire) and the Oconee Nuclear Station (Oconee) and operates and has a partial ownership interest in the Catawba Nuclear Station (Catawba). McGuire and Catawba each have two reactors. Oconee has three reactors. The other joint owners of Catawba reimburse Duke Energy Carolinas for certain expenses associated with nuclear insurance per the Catawba joint owner agreements.
	Duke Energy Progress owns and operates the Robinson Nuclear Station (Robinson) and operates and has a partial ownership interest in the Brunswick Nuclear Station (Brunswick) and Harris. Robinson and Harris each have one reactor. Brunswick has two reactors. The other joint owners of Brunswick and Harris reimburse Duke Energy Progress for certain expenses associated with nuclear insurance per the Brunswick and Harris joint owner agreements.
	Duke Energy Florida manages and has a partial ownership interest in Crystal River Unit 3, which has been retired. The other joint owners of Crystal River Unit 3 reimburse Duke Energy Florida for certain expenses associated with nuclear insurance per the Crystal River Unit 3 joint owner agreement.
	In the event of a loss, terms and amounts of insurance available might not be adequate to cover property damage and other expenses incurred. Uninsured losses and other expenses, to the extent not recovered by other sources, could have a material effect on Duke Energy Carolinas', Duke Energy Progress' and Duke Energy Florida's results of operations, cash flows or financial position. Each company is responsible to the extent losses may exceed limits of the coverage available.
	Nuclear Liability Coverage
	The Price-Anderson Act requires owners of nuclear reactors to provide for public nuclear liability protection per nuclear incident up to a maximum total financial protection liability. The maximum total financial protection liability increased to a total of $13.6 billion. This amount is adjusted every five years for an inflationary provision. Total nuclear liability coverage consists of a combination of private primary nuclear liability insurance coverage and a mandatory industry risk-sharing program to provide for excess nuclear liability coverage above the maximum reasonably available private primary coverage. The United States Congress could impose revenue-raising measures on the nuclear industry to pay claims.
	Primary Liability Insurance
	Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida have purchased the maximum reasonably available private primary nuclear liability insurance as required by law, which currently is $375 million per station.
	Excess Liability Program
	This program provides $13.2 billion of coverage per incident through the Price-Anderson Act's mandatory industry-wide excess secondary financial protection program of risk pooling. This amount is the product of potential cumulative retrospective premium assessments of $127 million times the current 104 licensed commercial nuclear reactors in U.S. Under this program, licensees could be assessed retrospective premiums to compensate for public nuclear liability damages in the event of a nuclear incident at any licensed facility in the U.S. Retrospective premiums may be assessed at a rate not to exceed $19 million per year per licensed reactor for each incident. The assessment may be subject to state premium taxes.
	Nuclear Property Coverage
	Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida are members of NEIL, which provides insurance coverage for nuclear facilities under three policy programs: the primary property insurance program, the excess property insurance program and the accidental outage insurance program.
	Pursuant to regulations of the NRC, each company's property damage insurance policies provide that all proceeds from such insurance be applied, first, to place the plant in a safe and stable condition after a qualifying accident, and second, to decontaminate the plant before any proceeds can be used for decommissioning, plant repair or restoration.
	Losses resulting from non-certified acts of terrorism are covered as common occurrences, such that if non-certified terrorist acts occur against one or more commercial nuclear power plants insured by NEIL within a 12-month period, they would be treated as one event and the owners of the plants where the act occurred would share one full limit of liability. The full limit of liability is currently $3.2 billion. NEIL sublimits the total aggregate for all of their policies for non-nuclear terrorist events to approximately $1.83 billion.
	Primary Property Insurance
	This policy provides $500 million of primary property damage coverage. The deductible per occurrence is $3 million for Catawba, and $10 million for the remaining nuclear facilities. This policy also has a 10 percent deductible provision excess of these deductibles for natural catastrophe damage.
	Excess Property Insurance
	This policy provides excess property, decontamination and decommissioning liability insurance of $2.25 billion for Catawba, $750 million each for Oconee, McGuire, Brunswick, Harris and Robinson; and $560 million for Crystal River Unit 3. All nuclear facilities except for Catawba and Crystal River Unit 3 also share an additional $1 billion insurance limit above their dedicated underlying excess. This shared additional excess limit is not subject to reinstatement in the event of a loss.
	Crystal River Unit 3's primary and excess property insurance is on an actual cash value basis. NEIL coverage does not include property damage to or resulting from the containment structure except 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.
	NEIL sublimits property damage losses to $1.5 billion for non-nuclear accidental property damage.
	Accidental Outage Insurance
	This policy provides replacement power expense coverage resulting from an accidental property damage outage of a nuclear unit. Coverage amounts decrease in the event more than one unit at a station is out of service due to a common accident. Initial coverage begins after a 12-week deductible period. Coverage continues at 100 percent of the weekly limits for 52 weeks and 80 percent of the weekly limits for the next 110 weeks.
	The Catawba units are insured for up to $4 million per week. The McGuire units are insured for up to $4 million per week. The Oconee units are insured for up to $3 million per week. The Brunswick units are insured for up to $3 million per week. The Harris unit is insured for up to $3 million per week. The Robinson unit is insured for up to $2 million per week. The accidental outage policy limit is $490 million for McGuire and Catawba, $378 million for Oconee, $406 million for Brunswick, $364 million for Harris, and $308 million for Robinson.
	NEIL sublimits the accidental outage recovery to the first 104 weeks of coverage not to exceed $328 million from non-nuclear accidental property damage.
	Potential Retroactive Premium Assessments
	In the event of NEIL losses, NEIL's board of directors may assess member companies retroactive premiums of amounts up to 10 times their annual premiums for up to six years after a loss. The current potential maximum assessments for Duke Energy Carolinas are $42 million for primary property insurance, $36 million for excess property insurance and $29 million for accidental outage insurance. The current potential maximum assessments for Duke Energy Progress are $33 million for primary property insurance, $32 million for excess property insurance and $14 million for accidental outage insurance. The current potential maximum assessments for Duke Energy Florida are $6 million for primary property insurance and $4 million for excess property insurance.
	The maximum assessment amounts include 100 percent of Duke Energy Carolinas', Duke Energy Progress', and Duke Energy Florida's potential obligations to NEIL for their share of jointly owned reactors. However, the other joint owners of the jointly owned reactors are obligated to assume their pro rata share of liability for retrospective premiums and other premium assessments resulting from the Price-Anderson Act's excess secondary financial protection program of risk pooling, or from the NEIL policies.
	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 potentially responsible parties, and may also benefit from insurance policies or contractual indemnities that cover some or all cleanup costs. Liabilities are recorded when losses become probable and are reasonably estimable. The total costs that may be incurred cannot be estimated because the extent of environmental impact, allocation among potentially responsible parties, remediation alternatives, and/or regulatory decisions has not yet been determined. Additional costs associated with remediation activities are likely to be incurred in the future and could be significant. Costs are typically expensed as Operation, maintenance and other in the 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 various environmental sites. These reserves are recorded in Other within Deferred Credits and Other Liabilities on the 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, 2010		$	88		$	13		$	35		$	12		$	23		$	50		$	11
	Provisions / adjustments			6			―			10			1			9			5			1
	Cash reductions			-33			-1			-22			-2			-20			-27			-3
	Balance at December 31, 2011			61			12			23			11			12			28			9
	Provisions / adjustments			39			1			19			5			14			5			3
	Cash reductions			-25			-1			-9			-2			-7			-18			-4
	Balance at December 31, 2012			75			12			33			14			19			15			8
	Provisions / adjustments			26			―			4			-1			5			20			1
	Cash reductions			-22			-1			-10			-5			-5			-8			-2
	Balance at December 31, 2013		$	79		$	11		$	27		$	8		$	19		$	27		$	7

	Additional losses in excess of recorded reserves that could be incurred for the stages of investigation, remediation and monitoring for environmental sites that have been evaluated at this time are presented in the table below.

	(in millions)
	Duke Energy		$	74
	Duke Energy Carolinas			29
	Progress Energy			5
	Duke Energy Progress			2
	Duke Energy Florida			3
	Duke Energy Ohio			35
	Duke Energy Indiana			5

Regulations
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. 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 revised deadline for issuance of the final 316(b) rule is April 17, 2014. If the rule is finalized as proposed, modifications to affected power plant cooling water intake structures could be required by mid-to-late 2017. The Duke Energy Registrants are unable to predict the outcome of this rulemaking, but the impact could be significant.
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 SO2 budgets and annual seasonal 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 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. 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 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 CCR or 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 directed the EPA to provide the Court, within 60 days of the Order, a proposed schedule for completing the CCR rulemaking. On January 29, 2014, the EPA filed a consent decree agreeing to issue the final rule by December 19, 2014. 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 finalize the 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 January 8, 2014, the EPA proposed a rule to establish carbon dioxide (CO2) emissions standards for new pulverized coal, IGCC, natural gas combined cycle, and simple cycle electric generating units commencing construction on or after the date the proposal appears in the Federal Register. Future coal and IGCC units will be required to employ carbon capture and storage technology to meet the proposed 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, but the impact could be significant.
Mercury and Air Toxics Standards (MATS)
The final MATS 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. 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.
Several petitions for review of the final rule were filed with the D.C. Circuit Court. A decision is expected in the first half of 2014. 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. 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 $4.5 billion to $5.5 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)
Duke Energy		$	525		to	$	625
Duke Energy Carolinas			40		to		50
Progress Energy			25		to		40
Duke Energy Progress			10		to		15
Duke Energy Florida			15		to		25
Duke Energy Ohio			35		to		50
Duke Energy Indiana			425		to		485

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. 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 rate 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
Dan River Ash Basin Release
On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy Carolinas' retired Dan River steam station caused a release of ash basin water and ash into the Dan River. On February 8, 2014, a permanent plug was installed in the stormwater pipe stopping the release of materials into the river. Duke Energy Carolinas estimates 30,000 to 39,000 tons of ash and 24 million to 27 million gallons of basin water were released into the river. Duke Energy Carolinas continues to work with local and state officials responding to this event. On February 10, 2014, Duke Energy received a subpoena for the production of documents, issued by the United States Attorney for the Eastern District of North Carolina in connection with a criminal investigation related to the release. A second subpoena was issued by the same United States Attorney on February 18, 2014, which expanded the document production to cover all fourteen of the North Carolina facilities with coal ash ponds.
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 matters.
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 eleven 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. The case is stayed pending resolution of the Nieman v. Duke Energy Corporation, et al. case in North Carolina.
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 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 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 various defendants including Duke Energy. 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 U.S. Court of Appeals for the Ninth Circuit 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, which remains pending.
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.
On November 15, 2013 the parties reached a settlement. Duke Energy recorded a net pretax charge of $22 million to Operations, maintenance and other in its Consolidated Statements of Operations related to the settlement in 2013.
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 the 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) on behalf of the EPA filed a number of complaints and notices of violation against multiple utilities, including Duke Energy Carolinas, for alleged violations of the NSR provisions of the CAA. The government alleges the utilities violated the CAA by not obtaining permits for certain projects undertaken at certain coal plants 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. 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 the NSR provisions. Duke Energy Carolinas asserts the projects were routine or not projected to increase emissions. The parties filed a stipulation in which the United States dismissed with prejudice 16 claims. In exchange, Duke Energy Carolinas dismissed certain affirmative defenses. The parties filed opposing motions for summary judgment on the remaining claims. In November 2013, the Court denied Duke Energy's motion for summary judgment. A decision on the DOJ's motion for summary judgment remains pending. Duke Energy 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, remains 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 recovery will be pursued for 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 December 31, 2013, there were 96 asserted claims for non-malignant cases with the cumulative relief sought of up to $24 million, and 31 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.
Duke Energy Carolinas has recognized asbestos-related reserves of $616 million at December 31, 2013 and $751 million at December 31, 2012. These reserves are classified in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities on the Consolidated Balance Sheets. These reserves are based upon the minimum amount of the range of loss for current and future asbestos claims through 2033, are recorded on an undiscounted basis and incorporate anticipated inflation. 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 at December 31, 2013 and $781 million at December 31, 2012. These amounts are classified in Other within Investments and Other Assets and Receivables on the 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 lawsuits arising out of a 1999 Asset Purchase Agreement. Parties to the Asset Purchase Agreement include U.S. Global, LLC (Global) and affiliates of Progress Energy.
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. 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 pretax 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 the second quarter of 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 Energy 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.
Progress Energy does not expect the resolution of these matters to have a material effect on it results of operations, cash flows or financial position.
Duke Energy Progress and Duke Energy Florida
Spent Nuclear Fuel Matters
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 a contract in failing to accept spent nuclear fuel under the Nuclear Waste Policy Act of 1982 and asserts damages for the cost of on-site storage. 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. 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 by entering into non-public option agreements in exchange for their withdrawal of challenges to Duke Energy Ohio's Rate Stabilization Plan (RSP) implemented in early 2005. 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 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 assessment may change as additional settlements occur, 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 significant 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 table below presents recorded reserves based on management's best estimate of probable loss for legal matters discussed above and the associated insurance recoveries. The reasonably possible range of loss for all non-asbestos related matters in excess of recorded reserves is not material.

		December 31,
(in millions)		2013			2012
Reserves for Legal and Other Matters^(a)
Duke Energy^(b)		$	824		$	846
Duke Energy Carolinas^(b)			616			751
Progress Energy			78			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)	Classified in the respective 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)	Classified in the respective 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 fully recognized on the Consolidated Balance Sheets and have unlimited maximum potential payments. However, the Duke Energy Registrants do not believe these guarantees will have a material effect on their results of operations, cash flows or financial position.
Purchase Obligations
Purchased Power
Duke Energy Progress, Duke Energy Florida, and Duke Energy Ohio have ongoing purchased power contracts, including renewable energy contracts, with other utilities, wholesale marketers, co-generators, and qualified facilities (QFs). These purchased power contracts generally provide for capacity and energy payments. In addition, Duke Energy Progress, Duke Energy Florida, and Duke Energy Ohio have various contracts to secure transmission rights.
The following table presents executory purchased power contracts, excluding contracts classified as leases.
						Minimum Purchase Amount at December 31, 2013
(in millions)			Contract Expiration		2014			2015			2016			2017			2018			Thereafter			Total
Duke Energy Progress^(a)			2019-2022		$	36			36		$	36		$	37		$	37		$	69		$	251
Duke Energy Florida^(b)			2014-2025			288			295			295			288			303			2,139			3,608
Duke Energy Ohio^(c)			2014-2015			250			97			―			―			―			―			347

(a)	Contracts represent 100 percent of net plant output.
(b)	Contracts represent between 2 percent and 100 percent of net plant output.
(c)	Contracts represent between 1 percent and 24 percent of net plant output.

Operating and Capital Lease Commitments
The Duke Energy Registrants lease office buildings, railcars, vehicles, computer equipment and other property and equipment with various terms and expiration dates. Additionally, Duke Energy Progress has a capital lease related to firm gas pipeline transportation capacity. Duke Energy Progress and Duke Energy Florida have entered into certain purchased power agreements, which are classified as leases. Consolidated capitalized lease obligations are classified as Long-term debt or Other within Current Liabilities on the Consolidated Balance Sheets. Amortization of assets recorded under capital leases is included in Depreciation and amortization and Fuel used in electric generation – regulated on the Consolidated Statements of Operations.
The following table presents rental expense for operating leases. These amounts are included in Operation, maintenance and other on the Consolidated Statements of Operations.

		Years Ended December 31,
(in millions)		2013		2012			2011
Duke Energy		$	321		$	232		$	104
Duke Energy Carolinas			39			38			43
Progress Energy			225			232			104
Duke Energy Progress			153			164			88
Duke Energy Florida			72			68			15
Duke Energy Ohio			14			14			19
Duke Energy Indiana			22			20			24

The following table presents future minimum lease payments under operating leases, which at inception had a non-cancelable term of more than one year.

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
2014		$	175		$	34		$	93		$	55		$	39		$	12		$	18
2015			159			29			89			51			39			11			15
2016			147			24			90			51			39			8			12
2017			137			20			89			50			39			7			9
2018			117			15			78			40			38			5			7
Thereafter			1,034			67			773			459			314			18			8
Total		$	1,769		$	189		$	1,212		$	706		$	508		$	61		$	69

The following table presents future minimum lease payments under capital leases.

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
2014		$	171		$	6		$	47		$	20		$	26		$	9		$	5
2015			167			6			47			20			27			7			4
2016			169			6			47			21			26			6			4
2017			166			6			46			21			26			3			2
2018			176			6			45			21			25			3			2
Thereafter			1,453			25			475			261			213			2			28
Minimum annual payments			2,302			55			707			364			343			30			45
Less amount representing interest			-786			-27			-454			-275			-179			-3			-30
Total		$	1,516		$	28		$	253		$	89		$	164		$	27		$	15

Debt_and_Credit_Facilities

Debt and Credit Facilities	12 Months Ended
Debt and Credit Facilities	Dec. 31, 2013
Debt And Credit Facilities [Abstract]	'
Debt And Credit Facilities	'

					31-Dec-13
	(in millions)				Duke Energy		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Facility size^(a)			$	6,000	$	2,250		$	1,000		$	750		$	650		$	650		$	700
	Reduction to backstop issuances
		Notes payable and commercial paper^(b)			-450		―			-300			―			―			―			-150
		Outstanding letters of credit			-62		-55			-4			-2			-1			―			―
		Tax-exempt bonds			-240		―			-75			―			―			-84			-81
	Available capacity			$	5,248	$	2,195		$	621		$	748		$	649		$	566		$	469

	(a)	Represents the sublimit of each borrower at December 31, 2013. The Duke Energy Ohio sublimit includes $100 million for Duke Energy Kentucky.
	(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 Carolinas' and Duke Energy Indiana's Condensed Consolidated Balance Sheets.


	(in millions)		Maturity Date	Interest Rate		31-Dec-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
	Tax-exempt Bonds
	Duke Energy Progress		Jan-14	0.105	%		167
	Other						387
	Current maturities of long-term debt					$	2,104


							Year Ended December 31, 2013
	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
	December 2013⁽ⁱ⁾		Dec-16	0.852	%			―			300			―			―			300
	First Mortgage Bonds
	March 2013^(j)		Mar-43	4.1	%			―			500			―			―			500
	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		$	800		$	450		$	500		$	4,023

	(a)	Callable after January 2018 at par. Proceeds were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS) and to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 17 for additional information about the QUIPS.
	(b)	Proceeds were used to repay $250 million of current maturities and for general corporate purposes, including the repayment of outstanding commercial paper.
	(c)	Proceeds 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 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 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)	Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Progress; the proceeds were used to repay short-term debt. See Note 17 for further details.
	(j)	Proceeds were used to repay notes payable to affiliated companies as well as for general corporate purposes.
	(k)	Proceeds 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 credit spread of 35 basis points.
	(m)	Proceeds 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.


							Year Ended December 31, 2012
	Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)		Duke Energy Carolinas		Progress Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy Indiana			Duke Energy
Unsecured Debt
March 2012^(a)		Apr-22	3.15	%		$	―	$	―	$	450	$	―	$	―	$	―	$	450
August 2012^(b)		Aug-17	1.63	%			700		―		―		―		―		―		700
August 2012^(b)		Aug-22	3.05	%			500		―		―		―		―		―		500
Secured Debt
April 2012^(c)		Sep-24	2.64	%			330		―		―		―		―		―		330
December 2012^(d)		Mar-13	2.77	%			203		―		―		―		―		―		203
December 2012^(d)		Mar-13	4.74	%			220		―		―		―		―		―		220
December 2012^(e)		Jun-13	1.01	%			190		―		―		―		―		―		190
December 2012^(e)		Dec-25	1.56	%			200		―		―		―		―		―		200
First Mortgage Bonds
March 2012^(f)		Mar-42	4.2	%			―		―		―		―		―		250		250
May 2012^(g)		May-22	2.8	%			―		―		―		500		―		―		500
May 2012^(g)		May-42	4.1	%			―		―		―		500		―		―		500
September 2012^(h)		Sep-42	4	%			―		650		―		―		―		―		650
November 2012⁽ⁱ⁾		Nov-15	0.65	%			―		―		―		―		250		―		250
November 2012⁽ⁱ⁾		Nov-42	3.85	%			―		―		―		―		400		―		400
Total Issuances						$	2,343	$	650	$	450	$	1,000	$	650	$	250	$	5,343

(a)	Proceeds were used to repay current maturities of $450 million.
(b)	Proceeds were used to repay current maturities of $500 million, as well as for general corporate purposes, including the repayment of commercial paper.
(c)	Proceeds were used to reimburse construction costs for DS Cornerstone, LLC joint venture wind projects. Debt was subsequently deconsolidated upon execution of a joint venture. See Note 17 for further details.
(d)	Proceeds were used to fund the existing Los Vientos wind power portfolio.
(e)	Debt issuances were executed in connection with the acquisition of Ibener. Both loans were collateralized with cash deposits equal to 101 percent of the loan amounts. See Note 2 for further details.
(f)	Proceeds were used to repay a portion of outstanding short-term debt.
(g)	Proceeds were used to repay current maturities of $500 million, a portion of outstanding commercial paper and notes payable to affiliated companies.
(h)	Proceeds were used to repay current maturities of $420 million, as well as for general corporate purposes, including the funding of capital expenditures.
(i)	Proceeds will be used to repay current maturities of $425 million, as well as for general corporate purposes.

6. DEBT AND CREDIT FACILITIES
Summary of Debt and Related Terms
The following tables summarize outstanding debt.

		31-Dec-13
(in millions)		Weighted Average Interest Rate		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Unsecured debt, maturing 2014 - 2073		5.18	%	$	13,550	$	1,157	$	4,150	$	―	$	150	$	805	$	744
Secured debt, maturing 2014 - 2037		2.69	%		2,559		400		305		305		―		―		―
First mortgage bonds, maturing 2015 - 2043^(a)		4.9	%		17,831		6,161		8,450		4,125		4,325		900		2,319
Capital leases, maturing 2014 - 2051^(b)		5.23	%		1,516		30		327		148		179		27		20
Other debt, maturing 2027		4.77	%		8		―		―		―		―		8		―
Tax-exempt bonds, maturing 2014 - 2041^(c)		1.28	%		2,356		395		910		669		241		479		573
Notes payable and commercial paper^(d)		1.02	%		1,289		―		―		―		―		―		―
Money pool/intercompany borrowings					―		300		1,213		462		181		43		150
Fair value hedge carrying value adjustment					9		9		―		―		―		―		―
Unamortized debt discount and premium, net^(e)					1,977		-16		-27		-12		-9		-31		-10
Total debt					41,095		8,436		15,328		5,697		5,067		2,231		3,796
Short-term notes payable and commercial paper					-839		―		―		―		―		―		―
Short-term money pool borrowings					―		―		-1,213		-462		-181		-43		―
Current maturities of long-term debt					-2,104		-47		-485		-174		-11		-47		-5
Total long-term debt^(f)				$	38,152	$	8,389	$	13,630	$	5,061	$	4,875	$	2,141	$	3,791

(a)	Substantially all electric utility fixed assets are mortgaged under mortgage bond indentures.
(b)	Duke Energy includes $144 million and $838 million of capital lease purchase accounting adjustments related to Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as leases in their financial statements because of grandfathering provisions in GAAP.
(c)	Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.
(d)	Includes $450 million that was classified as Long-term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energy’s ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 49 days.
(e)	Duke Energy includes $2,067 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.
(f)	Includes $1,966 million for Duke Energy, $400 million for Duke Energy Carolinas and $300 million for Progress Energy and Duke Energy Progress related to consolidated VIEs.


		31-Dec-12
(in millions)		Weighted Average Interest Rate			Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Unsecured debt, maturing 2013 - 2039		5.44	%		$	12,722	$	1,159	$	4,150	$	―	$	150	$	805	$	1,146
Secured debt, maturing 2013 - 2037		3.08	%			1,873		300		5		5		―		―		―
First mortgage bonds, maturing 2013 - 2042^(a)		5	%			17,856		6,562		8,775		4,025		4,750		700		1,819
Capital leases, maturing 2013 - 2051^(b)		5.19	%			1,689		32		339		150		189		35		23
Junior subordinated debt, maturing 2039		7.1	%			309		―		309		―		―		―		―
Other debt, maturing 2027		4.77	%			8		―		―		―		―		8		―
Tax exempt bonds, maturing 2014 - 2041^(c)		1.39	%			2,357		395		910		669		241		479		573
Notes payable and commercial paper^(d)		0.83	%			1,507		―		―		―		―		―		―
Money pool/intercompany borrowings						―		300		455		364		―		245		231
Fair value hedge carrying value adjustment						12		10		―		―		―		2		―
Unamortized debt discount and premium, net^(e)						2,185		-17		-60		-9		-10		-32		-9
Total debt						40,518		8,741		14,883		5,204		5,320		2,242		3,783
Short-term notes payable and commercial paper						-1,057		―		―		―		―		―		―
Short-term money pool borrowings						―		―		-455		-364		―		-245		-81
Current maturities of long-term debt						-3,110		-406		-843		-407		-435		-261		-405
Total long-term debt^(f)					$	36,351	$	8,335	$	13,585	$	4,433	$	4,885	$	1,736	$	3,297

(a)	Substantially all electric utility fixed assets are mortgaged under mortgage bond indentures.
(b)	Duke Energy includes $158 million and $907 million of capital lease purchase accounting adjustments for Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as leases on their financial statements because of grandfathering provisions in GAAP.
(c)	Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.
(d)	Includes $450 million that was classified as Long-term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energy’s ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 18 days.
(e)	Duke Energy includes $2,311 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.
(f)	Includes $852 million for Duke Energy and $300 million for Duke Energy Carolinas related to consolidated VIEs.

Current Maturities of Long-Term Debt
The following table shows the significant components of Current maturities of long-term debt on the respective Consolidated Balance Sheets. The Duke Energy Registrants currently anticipate satisfying these obligations primarily with cash on hand and proceeds from additional borrowings.

(in millions)		Maturity Date	Interest Rate		31-Dec-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
Tax-exempt Bonds
Duke Energy Progress		Jan-14	0.105	%		167
Other						387
Current maturities of long-term debt					$	2,104

Maturities and Call Options
The following table shows the annual maturities of long-term debt for the next five years and thereafter. Amounts presented exclude short-term notes payable and commercial paper and money pool borrowings for the Subsidiary Registrants.

		31-Dec-13
(in millions)		Duke Energy^(a)			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
2014		$	2,104		$	47		$	485		$	174		$	11		$	47		$	5
2015			2,634			507			1,264			702			562			157			5
2016			2,975			756			614			302			12			56			480
2017			1,342			116			265			3			262			2			3
2018			3,235			1,505			603			59			544			3			153
Thereafter			25,899			5,505			10,884			3,995			3,495			1,923			3,150
Total long-term debt, including current maturities		$	38,189		$	8,436		$	14,115		$	5,235		$	4,886		$	2,188		$	3,796

(a)	Excludes $2,067 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.

The Duke Energy Registrants have the ability under certain debt facilities to call and repay the obligation prior to its scheduled maturity. Therefore, the actual timing of future cash repayments could be materially different than as presented above.
Short-term Obligations Classified as Long-term Debt
Tax-exempt bonds that may be put to the Company at the option of the holder and certain commercial paper issuances and money pool borrowings are classified as Long-term debt on the Consolidated Balance Sheets. These tax-exempt bonds, commercial paper issuances and money pool borrowings, which are short-term obligations by nature, are classified as long term due to Duke Energy's intent and ability to utilize such borrowings as long-term financing. As Duke Energy's master credit facility and other bilateral letter of credit agreements have non-cancelable terms in excess of one year as of the balance sheet date, Duke Energy has the ability to refinance these short-term obligations on a long-term basis. The following tables show short-term obligations classified as long-term debt.

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Duke Energy Ohio			Duke Energy Indiana
Tax-exempt bonds		$	471		$	75		$	111		$	285
Notes payable and commercial paper			450			300			―			150
Secured debt^(a)			200			―			―			―
Total		$	1,121		$	375		$	111		$	435


		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Duke Energy Ohio			Duke Energy Indiana
Tax exempt bonds		$	471		$	75		$	111		$	285
Notes payable and commercial paper			450			300			―			150
Secured debt^(a)			200			―			―			―
DERF^(b)			300			300
Total		$	1,421		$	675		$	111		$	435

(a)	Instrument has a term of less than one year with the right to extend the maturity date for additional one-year periods with a final maturity date no later than December 2026.
(a)	Duke Energy Receivables Finance Company, LLC (DERF) is a wholly owned limited liability company of Duke Energy Carolinas. See Note 17 for further information.

Summary of SIGNIFICANT Debt ISSUANCES
The following tables summarize significant debt issuances (in millions).


						Year Ended December 31, 2013
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
December 2013⁽ⁱ⁾		Dec-16	0.852	%			―			300			―			―			300
First Mortgage Bonds
March 2013^(j)		Mar-43	4.1	%			―			500			―			―			500
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		$	800		$	450		$	500		$	4,023

(a)	Callable after January 2018 at par. Proceeds were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS) and to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 17 for additional information about the QUIPS.
(b)	Proceeds were used to repay $250 million of current maturities and for general corporate purposes, including the repayment of outstanding commercial paper.
(c)	Proceeds 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 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 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)	Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Progress; the proceeds were used to repay short-term debt. See Note 17 for further details.
(j)	Proceeds were used to repay notes payable to affiliated companies as well as for general corporate purposes.
(k)	Proceeds 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 credit spread of 35 basis points.
(m)	Proceeds 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.


						Year Ended December 31, 2012
Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)		Duke Energy Carolinas		Progress Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy Indiana			Duke Energy
Unsecured Debt
March 2012^(a)		Apr-22	3.15	%		$	―	$	―	$	450	$	―	$	―	$	―	$	450
August 2012^(b)		Aug-17	1.63	%			700		―		―		―		―		―		700
August 2012^(b)		Aug-22	3.05	%			500		―		―		―		―		―		500
Secured Debt
April 2012^(c)		Sep-24	2.64	%			330		―		―		―		―		―		330
December 2012^(d)		Mar-13	2.77	%			203		―		―		―		―		―		203
December 2012^(d)		Mar-13	4.74	%			220		―		―		―		―		―		220
December 2012^(e)		Jun-13	1.01	%			190		―		―		―		―		―		190
December 2012^(e)		Dec-25	1.56	%			200		―		―		―		―		―		200
First Mortgage Bonds
March 2012^(f)		Mar-42	4.2	%			―		―		―		―		―		250		250
May 2012^(g)		May-22	2.8	%			―		―		―		500		―		―		500
May 2012^(g)		May-42	4.1	%			―		―		―		500		―		―		500
September 2012^(h)		Sep-42	4	%			―		650		―		―		―		―		650
November 2012⁽ⁱ⁾		Nov-15	0.65	%			―		―		―		―		250		―		250
November 2012⁽ⁱ⁾		Nov-42	3.85	%			―		―		―		―		400		―		400
Total Issuances						$	2,343	$	650	$	450	$	1,000	$	650	$	250	$	5,343

(a)	Proceeds were used to repay current maturities of $450 million.
(b)	Proceeds were used to repay current maturities of $500 million, as well as for general corporate purposes, including the repayment of commercial paper.
(c)	Proceeds were used to reimburse construction costs for DS Cornerstone, LLC joint venture wind projects. Debt was subsequently deconsolidated upon execution of a joint venture. See Note 17 for further details.
(d)	Proceeds were used to fund the existing Los Vientos wind power portfolio.
(e)	Debt issuances were executed in connection with the acquisition of Ibener. Both loans were collateralized with cash deposits equal to 101 percent of the loan amounts. See Note 2 for further details.
(f)	Proceeds were used to repay a portion of outstanding short-term debt.
(g)	Proceeds were used to repay current maturities of $500 million, a portion of outstanding commercial paper and notes payable to affiliated companies.
(h)	Proceeds were used to repay current maturities of $420 million, as well as for general corporate purposes, including the funding of capital expenditures.
(i)	Proceeds will be used to repay current maturities of $425 million, as well as for general corporate purposes.

Available Credit Facilities
Duke Energy has a master credit facility with a capacity of $6 billion through December 2018. The Subsidiary Registrants, excluding Progress Energy 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. The amount available under the master credit facility has been reduced to backstop the 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. The table below includes the current borrowing sublimits and available capacity under the master credit facility.

				31-Dec-13
(in millions)				Duke Energy		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Facility size^(a)			$	6,000	$	2,250		$	1,000		$	750		$	650		$	650		$	700
Reduction to backstop issuances
	Notes payable and commercial paper^(b)			-450		―			-300			―			―			―			-150
	Outstanding letters of credit			-62		-55			-4			-2			-1			―			―
	Tax-exempt bonds			-240		―			-75			―			―			-84			-81
Available capacity			$	5,248	$	2,195		$	621		$	748		$	649		$	566		$	469

(a)	Represents the sublimit of each borrower at December 31, 2013. The Duke Energy Ohio sublimit includes $100 million for Duke Energy Kentucky.
(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 Carolinas' and Duke Energy Indiana's Condensed Consolidated Balance Sheets.

Other Debt Matters
In September 2013, Duke Energy filed a registration statement (Form S-3) with the SEC. Under this Form S-3, which is uncapped, the Duke Energy Registrants, excluding Progress Energy, may issue debt and other securities in the future at amounts, prices and with terms to be determined at the time of future offerings. The registration statement also allows for the issuance of common stock by Duke Energy.
Duke Energy has an effective Form S-3 with the SEC to sell up to $3 billion of variable denomination floating-rate demand notes, called PremierNotes. The Form S-3 states that no more than $1.5 billion of the notes will be outstanding at any particular time. The notes are offered on a continuous basis and bear interest at a floating rate per annum determined by the Duke Energy PremierNotes Committee, or its designee, on a weekly basis. The interest rate payable on notes held by an investor may vary based on the principal amount of the investment. The notes have no stated maturity date, are non-transferable and may be redeemed in whole or in part by Duke Energy or at the investor's option at any time. The balance as of December 31, 2013 and 2012 was $836 million and $395 million, respectively. The notes are short-term debt obligations of Duke Energy and are reflected as Notes payable and commercial paper on Duke Energy's Consolidated Balance Sheets.
At December 31, 2013 and 2012, $811 million and $734 million, respectively, of debt issued by Duke Energy Carolinas was guaranteed by Duke Energy.
Money Pool
The Subsidiary Registrants, excluding Progress Energy receive support for their short-term borrowing needs through participation with Duke Energy and certain of its subsidiaries in a money pool arrangement. Under this arrangement, those companies with short-term funds may provide short-term loans to affiliates participating in this arrangement. The money pool is structured such that the Subsidiary Registrants, excluding Progress Energy separately manage their cash needs and working capital requirements. Accordingly, there is no net settlement of receivables and payables between money pool participants. Duke Energy (Parent), may loan funds to its participating subsidiaries, but may not borrow funds through the money pool. Accordingly, as the money pool activity is between Duke Energy and its wholly owned subsidiaries, all money pool balances are eliminated within Duke Energy's Consolidated Balance Sheets.
Money pool receivable balances are reflected within Notes receivable from affiliated companies on the respective Subsidiary Registrants' Consolidated Balance Sheets. Money pool payable balances are reflected within either Notes payable to affiliated companies or Long-term debt payable to affiliated companies on the respective Consolidated Balance Sheets.
Restrictive Debt Covenants
The Duke Energy Registrants' debt and credit agreements contain various financial and other covenants. The master credit facility contains a covenant requiring the debt-to-total capitalization ratio not exceed 65 percent for each borrower. Failure to meet those covenants beyond applicable grace periods could result in accelerated due dates and/or termination of the agreements. As of December 31, 2013, each of the Duke Energy Registrants were in compliance with all covenants related to its significant debt agreements. In addition, some credit agreements may allow for acceleration of payments or termination of the agreements due to nonpayment, or acceleration of other significant indebtedness of the borrower or some of its subsidiaries. None of the significant debt or credit agreements contain material adverse change clauses.
Other Loans
During 2013 and 2012, Duke Energy and Duke Energy Progress had loans outstanding against the cash surrender value of life insurance policies it owns on the lives of its executives. The amounts outstanding were $571 million, including $48 million at Duke Energy Progress and $496 million as of December 31, 2013 and 2012, respectively. The amounts outstanding were carried as a reduction of the related cash surrender value that is included in Other within Investments and Other Assets on the Consolidated Balance Sheets.

Guarantees_and_Indemnification

Guarantees and Indemnifications	12 Months Ended
	Dec. 31, 2013
Guarantees [Abstract]	'
Guarantees and Indemnifications	'
	7. GUARANTEES AND INDEMNIFICATIONS
	Duke Energy and Progress Energy have various financial and performance guarantees and indemnifications, which are issued in the normal course of business. As discussed below, these contracts include performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications. Duke Energy and Progress Energy enter into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. At December 31, 2013, Duke Energy and Progress Energy do not believe conditions are likely for significant performance under these guarantees. To the extent liabilities are incurred as a result of the activities covered by the guarantees, such liabilities are included on the accompanying Consolidated Balance Sheets.
	On January 2, 2007, Duke Energy completed the spin-off of its natural gas businesses to shareholders. Guarantees issued by Duke Energy or its affiliates, or assigned to Duke Energy prior to the spin-off, remained with Duke Energy subsequent to the spin-off. Guarantees issued by Spectra Energy Capital, LLC, formerly known as Duke Capital LLC, (Spectra Capital) or its affiliates prior to the spin-off remained with Spectra Capital subsequent to the spin-off, except for guarantees that were later assigned to Duke Energy. Duke Energy has indemnified Spectra Capital against any losses incurred under certain of the guarantee obligations that remain with Spectra Capital. At December 31, 2013, the maximum potential amount of future payments associated with these guarantees was $205 million, the majority of which expires by 2028.
	Duke Energy has issued performance guarantees to customers and other third parties that guarantee the payment and performance of other parties, including certain non-wholly owned entities, as well as guarantees of debt of certain non-consolidated entities and less than wholly owned consolidated entities. If such entities were to default on payments or performance, Duke Energy would be required under the guarantees to make payments on the obligations of the less than wholly owned entity. The maximum potential amount of future payments required under these guarantees as of December 31, 2013, was $285 million. Of this amount, $15 million relates to guarantees issued on behalf of less than wholly owned consolidated entities, with the remainder related to guarantees issued on behalf of third parties and unconsolidated affiliates of Duke Energy. Of the guarantees noted above, $102 million of the guarantees expire between 2015 and 2033, with the remaining performance guarantees having no contractual expiration.
	Duke Energy has guaranteed certain issuers of surety bonds, obligating itself to make payment upon the failure of a wholly owned and former non-wholly owned entity to honor its obligations to a third party. Under these arrangements, Duke Energy has payment obligations that are triggered by a draw by the third party or customer due to the failure of the wholly owned or former non-wholly owned entity to perform according to the terms of its underlying contract. At December 31, 2013, Duke Energy had guaranteed $92 million of outstanding surety bonds. Of this amount, $54 million, expire in 2014, the remaining expires between 2015 – 2021.
	At December 31, 2013, Duke Energy had $457 million of unused bank-issued stand-by letters of credit to secure the performance of wholly owned and non-wholly owned entities to a third party or customer.
	Duke Energy and Progress Energy has issued indemnifications for certain asset performance, legal, tax and environmental matters to third parties, including indemnifications made in connection with sales of businesses. At December 31, 2013, the estimated maximum exposure for these indemnifications was $117 million, the majority of which expires in 2017. Of this amount, $7 million has no contractual expiration. For certain matters for which Progress Energy receives timely notice, indemnity obligations may extend beyond the notice period. Certain indemnifications related to discontinued operations have no limitations as to time or maximum potential future payments.
	The following table includes the liabilities recognized for the guarantees discussed above. These amounts are primarily recorded in Other within Deferred Credits and other Liabilities on the Consolidated Balance Sheets. As current estimates change, additional losses related to guarantees and indemnifications to third parties, which could be material, may be recorded by the Duke Energy Registrants in the future. The decrease in 2013 was mainly due the expiration of guarantees. Accruals and expenditures were not material.

		December 31,
		2013			2012
	Duke Energy		$	24		$	41
	Progress Energy			9			25
	Duke Energy Florida			3			17

Joint_Ownership_Of_Generating_

Joint Ownership Of Generating and Transmission Facilities	12 Months Ended
Joint Ownership Of Generating and Transmission Facilities	Dec. 31, 2013
Joint Ownership Of Generating And Transmission Facilities [Abstract]	'
Joint Ownership Of Generating And Transmission Facilities	'
	8. Joint Ownership of Generating and Transmission Facilities
	The Duke Energy Registrants hold ownership interests in certain jointly owned generating and transmission facilities. The Duke Energy Registrants are entitled to shares of the generating capacity and output of each unit equal to their respective ownership interests. The Duke Energy Registrants pay their ownership share of additional construction costs, fuel inventory purchases and operating expenses, except in certain instances where agreements have been executed to limit certain joint owners' maximum exposure to the additional costs. The Duke Energy Registrants share of revenues and operating costs of the jointly owned generating facilities is included within the corresponding line in the Consolidated Statements of Operations. Each participant in the jointly owned facilities must provide its own financing, except in certain instances where agreements have been executed to limit certain joint owners' maximum exposure to the additional costs.
	The following table presents the share of jointly owned plant or facilities included on the Consolidated Balance Sheets. All facilities are operated by the Duke Energy Registrants unless otherwise noted.

			31-Dec-13
			Ownership Share		Property, Plant and Equipment		Accumulated Depreciation		Construction Work in Progress
	Duke Energy Carolinas
		Catawba Nuclear Station (Units 1 and 2)^(a)(b)	19.25	%	$	887	$	498	$	―
	Duke Energy Progress
		Mayo Station^(a)(c)	83.83			856		303		104
		Shearon Harris Nuclear Station^(a)(c)	83.83			3,620		2,018		67
		Brunswick Nuclear Station^(a)(c)	81.67			1,921		1,005		176
		Roxboro Station (Unit 4)^(a)(c)	87.06			754		473		13
	Duke Energy Florida
		Crystal River Nuclear Station (Unit 3)^(a)(d)	91.78			―		―		―
		Intercession City Station (Unit P11)^(a)(e)	66.67			25		13		―
	Duke Energy Ohio
		Miami Fort Station (Units 7 and 8)^(f)(g)	64			624		232		1
		W.C. Beckjord Station (Unit 6)^(f)(h)	37.5			―		―		―
		J.M. Stuart Station^(f)(h)(i)	39			823		281		16
		Conesville Station (Unit 4)^(f)(h)(i)	40			318		49		3
		W.M. Zimmer Station^(f)(h)	46.5			1,358		574		4
		Killen Station^(f)(g)(i)	33			308		139		2
		East Bend Station^(a)(g)	69			447		240		13
		Transmission facilities^(a)(h)	Various			96		49		―
	Duke Energy Indiana
		Gibson Station (Unit 5)^(a)(j)	50.05			308		160		2
		Vermillion^(a)(k)	62.5			154		61		―
		Transmission and local facilities^(a)(j)	Various			3,726		1,582		―
	International Energy
		Brazil - Canoas I and II^(l)	47.2			266		83		―

	(a)	Included in Regulated Utilities segment.
	(b)	Co-owned with North Carolina Municipal Power Agency Number 1, NCEMC and Piedmont Municipal Power Agency.
	(c)	Co-owned with North Carolina Eastern Municipal Power Agency.
	(d)	All costs associated with Crystal River Unit 3 are included within Regulatory assets on the Consolidated Balance Sheets of Duke Energy, Progress Energy and Duke Energy Florida. See Note 4 for additional information. Co-owned with Seminole Electric Cooperative, Inc., City of Ocala, Orlando Utilities Commission, City of Gainesville, City of Leesburg, Kissimmee Utility Authority, Utilities Commission of the City of New Smyrna Beach, City of Alachua and City of Bushnell.
	(e)	Co-owned with Georgia Power Company. Georgia Power Company has exclusive rights to the output of the unit during the months of June through September.
	(f)	Included in Commercial Power segment.
	(g)	Co-owned with The Dayton Power and Light Company.
	(h)	Co-owned with The Dayton Power and Light Company and Ohio Power Company.
	(i)	Station is not operated by Duke Energy Ohio.
	(j)	Co-owned with WVPA and Indiana Municipal Power Agency.
	(k)	Co-owned with WVPA.
	(l)	Included in International Energy segment. Co-owned with Companhia Brasileira de Aluminio.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2013
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligations	'
	9. Asset Retirement Obligations
	Asset retirement obligations recognized by Duke Energy Carolinas, Progress Energy, Duke Energy Progress and Duke Energy Florida relate primarily to decommissioning nuclear power facilities, asbestos removal and closure of landfills at fossil generation facilities. Asset retirement obligations at Duke Energy Ohio relate primarily to the retirement of gas mains, asbestos removal and closure of landfills at fossil generation facilities. Asset retirement obligations at Duke Energy Indiana relate primarily to obligations associated with asbestos removal and closure of landfills at fossil generation facilities. Duke Energy also has asset retirement obligations related to the removal of renewable energy generation assets in addition to the above items. Certain of the Duke Energy Registrants' assets have an indeterminate life, such as transmission and distribution facilities, and thus the fair value of the retirement obligation is not reasonably estimable. A liability for these asset retirement obligations will be recorded when a fair value is determinable.
	The following table presents changes in the liability associated with asset retirement obligations.

	(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		$	1,936	$	1,846	$	1,265	$	896	$	369	$	27	$	43
	Acquisitions^(a)			3,062		—		—		—		—		—		—
	Accretion expense^(b)			173		118		86		64		22		1		1
	Liabilities settled			-15		-3		-2		-2		—		—		-10
	Revisions in estimates of cash flows^(c)			-4		-2		234		—		234		—		-1
	Liabilities incurred in the current year^(d)			24		—		837		698		139		—		4
	Balance at December 31, 2012^(e)			5,176		1,959		2,420		1,656		764		28		37
	Acquisitions			4		—		—		—		—		—		—
	Accretion expense^(b)			239		122		113		80		33		2		—
	Liabilities settled			-12		—		-12		—		-12		—		—
	Revisions in estimates of cash flows^(f)			-449		-487		49		1		48		-2		-7
	Balance at December 31, 2013^(e)		$	4,958	$	1,594	$	2,570	$	1,737	$	833	$	28	$	30

	(a)	Represents asset retirement obligations resulting from the merger with Progress Energy. See Note 2 for additional information.
	(b)	Substantially all accretion expense for the years ended December 31, 2013 and 2012 relates to Duke Energy’s regulated electric operations and has been deferred in accordance with regulatory accounting treatment.
	(c)	For Progress Energy and Duke Energy Florida, the amounts relate to the retirement of Crystal River Unit 3.
	(d)	For Progress Energy, Duke Energy Progress and Duke Energy Florida, amounts primarily relate to spent nuclear fuel disposal recorded in the third quarter of 2012 to conform to Duke Energy's assumptions for nuclear asset retirement obligations.
	(e)	Balances at December 31, 2013 and 2012, include $8 million and $7 million, respectively, reported in Other current liabilities on the Consolidated Balance Sheets at Duke Energy, Progress Energy and Duke Energy Progress.
	(f)	Amounts for Duke Energy, Duke Energy Carolinas and Duke Energy Florida primarily relate to the site-specific nuclear decommissioning cost studies completed in 2013.


	The Duke Energy Registrants' regulated operations accrue costs of removal for property that does not have an associated legal retirement obligation based on regulatory orders from state commissions. These costs of removal are recorded as a regulatory liability in accordance with regulatory accounting treatment. The Duke Energy Registrants do not accrue the estimated cost of removal for any nonregulated assets. See Note 4 for the estimated cost of removal for assets without an associated legal retirement obligation, which are included in Regulatory liabilities on the Consolidated Balance Sheets.
	Nuclear Decommissioning Costs
	Use of the NDTF investments are restricted to nuclear decommissioning activities. The NDTF investments are managed and invested in accordance with applicable requirements of various regulatory bodies, including the NRC, FERC, NCUC, PSCSC, FPSC and the Internal Revenue Service (IRS). The fair value of assets legally restricted for purposes of settling asset retirement obligations associated with nuclear decommissioning are $4,769 million and $2,477 million for Duke Energy and Duke Energy Carolinas at December 31, 2013, respectively, and $3,941 million and $2,053 million for Duke Energy and Duke Energy Carolinas at December 31, 2012, respectively. The NDTF balances for Progress Energy, Duke Energy Progress and Duke Energy Florida represent the fair value of assets legally restricted for purposes of settling asset retirement obligations associated with nuclear decommissioning. The NCUC, PSCSC and FPSC require updated cost estimates for decommissioning nuclear plants every five years.
	The following table summarizes information about nuclear decommissioning cost studies.

	(in millions)		Annual Funding Requirement		Decommissioning Costs^(a)(b)		Year of Cost Study
	Duke Energy Carolinas		$	21	$	3,420	2013
	Duke Energy Progress			14		3,000	2009
	Duke Energy Florida			―		1,083	2013

	(a)	Represents cost per the most recent site-specific nuclear decommissioning cost studies, including costs to decommission plant components not subject to radioactive contamination.
	(b)	Includes the Duke Energy Registrants' ownership interest in jointly owned reactors. Other joint owners are responsible for decommissioning costs related to their interest in the reactors.

	Nuclear Operating Licenses
	Operating licenses for nuclear units are subject to extension. The following table includes the current expiration of nuclear operating licenses.


	Unit			Year of Expiration
	Duke Energy Carolinas
	Catawba Unit 1			2043
	Catawba Unit 2			2043
	McGuire Unit 1			2041
	McGuire Unit 2			2043
	Oconee Unit 1			2033
	Oconee Unit 2			2033
	Oconee Unit 3			2034
	Duke Energy Progress
	Brunswick Unit 1			2036
	Brunswick Unit 2			2034
	Harris			2046
	Robinson			2030
	Duke Energy Florida
	Crystal River Unit 3^(a)			2016

	(a)	Duke Energy Florida has requested the NRC terminate the Crystal River Unit 3 operating license as a result of the retirement of the unit.

Property_Plant_Equipment

Property, Plant & Equipment	12 Months Ended
Property, Plant & Equipment	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment	'
	10. PROPERTY, PLANT AND EQUIPMENT
	The following tables summarize the property, plant and equipment.

							31-Dec-13
	(in millions)		Estimated Useful Life (Years)					Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Land						$	1,481	$	397	$	705	$	383	$	321	$	137	$	105
	Plant - Regulated
		Electric generation, distribution and transmission	2	-	125			78,272		30,018		31,792		19,190		12,601		3,925		11,594
		Natural gas transmission and distribution	12	-	67			2,138		―		―		―		―		2,138		―
		Other buildings and improvements	2	-	100			1,397		447		610		282		315		190		159
	Plant - Nonregulated
		Electric generation, distribution and transmission	2	-	100			6,267		―		―		―		―		4,017		―
		Other buildings and improvements	9	-	100			2,512		―		―		―		―		5		―
	Nuclear fuel							2,458		1,446		1,012		1,012		―		―		―
	Equipment		1	-	33			1,557		287		621		357		94		317		146
	Construction in process							3,595		1,741		873		631		238		166		307
	Other		5	-	33			3,438		570		867		418		294		248		178
	Total property, plant and equipment^(a)(d)							103,115		34,906		36,480		22,273		13,863		11,143		12,489
	Total accumulated depreciation - regulated^(b)(c)(d)							-31,659		-11,894		-13,098		-8,623		-4,252		-2,160		-3,913
	Total accumulated depreciation - nonregulated^(c)(d)							-1,966		―		―		―		―		-748		―
	Total net property, plant and equipment						$	69,490	$	23,012	$	23,382	$	13,650	$	9,611	$	8,235	$	8,576

	(a)	Includes capitalized leases of $1,606 million, $53 million, $328 million, $148 million, $180 million, $96 million, and $30 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $60 million, an insignificant amount and $57 million, respectively, of accumulated amortization of capitalized leases.
	(b)	Includes $1,118 million, $681 million, $438 million and $438 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.
	(c)	Includes accumulated amortization of capitalized leases of $40 million, $4 million, $21 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.
	(d)	Includes gross property, plant and equipment cost of consolidated VIEs of $1,678 million and accumulated depreciation of consolidated VIEs of $175 million at Duke Energy.


							31-Dec-12
	(in millions)		Estimated Useful Life (Years)					Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Land						$	1,368	$	378	$	618	$	380	$	239	$	136	$	90
	Plant - Regulated
		Electric generation, distribution and transmission	2	-	138			73,181		29,269		30,250		18,009		12,041		3,774		8,622
		Natural gas transmission and distribution	12	-	60			2,026		―		―		―		―		2,026		―
		Other buildings and improvements	2	-	100			1,319		444		609		283		318		125		149
	Plant - Nonregulated
		Electric generation, distribution and transmission	2	-	100			6,055		―		―		―		―		3,870		―
		Other buildings and improvements	9	-	90			2,940		―		―		―		―		191		―
	Nuclear fuel							2,127		1,277		850		850		―		―		―
	Equipment		1	-	34			1,448		279		604		336		90		255		141
	Construction in process							6,655		1,996		1,424		946		474		204		2,836
	Other		5	-	60			3,272		547		791		380		270		243		174
	Total property, plant and equipment^(a)(d)							100,391		34,190		35,146		21,184		13,432		10,824		12,012
	Total accumulated depreciation - regulated^(b)(c)(d)							-29,471		-11,437		-12,512		-8,185		-4,072		-1,995		-3,692
	Total accumulated depreciation - nonregulated^(c)(d)							-2,498		―		―		―		―		-703		―
	Generation facilities to be retired, net							136		73		63		63		―		―		―
	Total net property, plant and equipment						$	68,558	$	22,826	$	22,697	$	13,062	$	9,360	$	8,126	$	8,320

	(a)	Includes capitalized leases of $1,844 million, $53 million, $339 million, $150 million, $189 million, $86 million, and $28 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $49 million, an insignificant amount and $48 million, respectively, of accumulated amortization of capitalized leases.
	(b)	Includes $857 million, $557 million, $300 million and $300 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.
	(c)	Includes accumulated amortization of capitalized leases of $34 million, $3 million, $12 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.
	(d)	Includes gross property, plant and equipment cost of consolidated VIEs of $1,558 million and accumulated depreciation of consolidated VIEs of $103 million at Duke Energy.

	The following table presents capitalized interest, which includes the debt component of AFUDC.

			Years Ended December 31,
	(in millions)			2013		2012		2011
	Duke Energy		$	90	$	177	$	166
	Duke Energy Carolinas			41		72		78
	Progress Energy			19		41		35
	Duke Energy Progress			16		23		20
	Duke Energy Florida			3		18		15
	Duke Energy Ohio			12		15		9
Duke Energy Indiana			9		39		33

Goodwill_and_Intangible_Assets

Goodwill and Intangible Assets	12 Months Ended
Goodwill and Intangible Assets	Dec. 31, 2013
Goodwill and Intangibles [Abstract]	'
Goodwill and Intangible Assets	'
	11. GOODWILL AND INTANGIBLE ASSETS
	Goodwill
	The following tables present goodwill by reportable operating segment for Duke Energy and Duke Energy Ohio.
	Duke Energy

	(in millions)			Regulated Utilities			International Energy			Commercial Power			Total
	Balance at December 31, 2012
	Goodwill			$	15,950		$	353		$	933		$	17,236
	Accumulated impairment charges				―			―			-871			-871
	Balance at December 31, 2012, as adjusted for accumulated impairment charges				15,950			353			62			16,365
	Acquisitions ^(a)				2			-5			2			-1
	Foreign exchange and other changes				-2			-22			―			-24
	Balance at December 31, 2013
	Goodwill				15,950			326			935			17,211
	Accumulated impairment charges				―			―			-871			-871
	Balance at December 31, 2013, as adjusted for accumulated impairment charges			$	15,950		$	326		$	64		$	16,340

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

	Duke Energy Ohio

	(in millions)		Regulated Utilities			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 December 31, 2013
	Goodwill			1,136			1,188			2,324
	Accumulated impairment charges			-216			-1,188			-1,404
	Balance at December 31, 2013, as adjusted for accumulated impairment charges		$	920		$	―		$	920

	Progress Energy
	Progress Energy had Goodwill of $3,655 million as of December 31, 2013 and 2012, for which there are no accumulated impairment charges.
	Impairment Analysis
	As the fair values of the reporting units of Duke Energy, Progress Energy and Duke Energy Ohio exceeded their respective carrying values at the date of the annual goodwill impairment analysis, no impairment charges were recorded.
	In addition, at December 31, 2013, goodwill for the Renewables reporting unit within Commercial Power was analyzed for impairment primarily as a result of the expiration of wind production tax credits at the end of 2013. Based on results of the fourth quarter 2013 impairment analysis, the fair value of the Renewables reporting unit exceeded its carrying value and no impairment was recorded. The fair value of the Renewables reporting unit is impacted by a multitude of factors, including legislative actions related to tax credit extensions, long-term growth rate assumptions, the market price of power and discount rates. Management continues to monitor these assumptions for any indicators that the fair value of the reporting unit could be below the carrying value, and will assess goodwill for impairment as appropriate.

	Intangible Assets
	The following tables show the carrying amount and accumulated amortization of intangible assets.

			31-Dec-13
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Emission allowances		$	63		$	1		$	21		$	3		$	18		$	20		$	21
	Renewable energy certificates			82			16			64			64			―			2			―
	Gas, coal and power contracts			180			―			―			―			―			156			24
	Wind development rights			86			―			―			―			―			―			―
	Other			76			―			―			―			―			―			―
	Total gross carrying amounts			487			17			85			67			18			178			45
	Accumulated amortization - gas, coal and power contracts			-73			―			―			―			―			-60			-13
	Accumulated amortization - wind development rights			-12			―			―			―			―			―			―
	Accumulated amortization - other			-24			―			―			―			―			―			―
	Total accumulated amortization			-109			―			―			―			―			-60			-13
	Total intangible assets, net		$	378		$	17		$	85		$	67		$	18		$	118		$	32

			31-Dec-12
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Emission allowances		$	80		$	―		$	26		$	4		$	22		$	24		$	29
	Renewable energy certificates			18			14			2			1			―			―			―
	Gas, coal and power contracts			295			―			―			―			―			272			24
	Wind development rights			111			―			―			―			―			―			―
	Other			91			―			―			―			―			10			―
	Total gross carrying amounts			595			14			28			5			22			306			53
Accumulated amortization - gas, coal and power contracts			-180			―			―			―			―			-168			-12
Accumulated amortization - wind development rights			-9			―			―			―			―			―			―
Accumulated amortization - other			-34			―			―			―			―			-9			―
Total accumulated amortization			-223			―			―			―			―			-177			-12
Total intangible assets, net		$	372		$	14		$	28		$	5		$	22		$	129		$	41

Impairment of Emission Allowances
On August 8, 2011, the EPA's final rule to replace CAIR was published in the Federal Register. As further discussed in Note 5, CSAPR established state-level annual SO2 and NOx caps that were required to take effect on January 1, 2012, and state-level ozone-season NOx caps that were to take effect on May 1, 2012. CSAPR did not utilize CAA emission allowances as the original CAIR provided. Under CSAPR, the EPA was expected to issue new emission allowances to be used exclusively for purposes of complying with CSAPR cap-and-trade program. After this ruling was published in 2011, Duke Energy evaluated the effect of CSAPR on the carrying value of emission allowances recorded at its Regulated Utilities and Commercial Power segments. Based on the provisions of CSAPR, Duke Energy Ohio had more SO2 allowances than were needed to comply with the continuing CAA acid rain cap-and-trade program (excess emission allowances). Duke Energy Ohio incurred a pretax impairment of $79 million in 2011 to write down the carrying value of excess emission allowances held by Commercial Power to fair value. The charge is recorded in Goodwill and other impairment charges on Duke Energy Ohio's Consolidated Statements of Operations. This amount was based on the fair value of excess allowances held by Commercial Power for compliance under the continuing CAA acid rain cap-and-trade program as of September 30, 2011.
Amortization Expense

The following table presents amortization expense for gas, coal and power contracts, wind development rights and other intangible assets.

		December 31,
(in millions)			2013			2012			2011
Duke Energy		$	13		$	14		$	10
Duke Energy Ohio			8			12			8
Duke Energy Indiana			1			1			1

The table below shows the expected amortization expense for the next five years for intangible assets as of December 31, 2013. The expected amortization expense includes estimates of emission allowances consumption and estimates of consumption of commodities such as gas and coal under existing contracts, as well as estimated amortization related to the wind development projects. The amortization amounts discussed below are estimates and actual amounts may differ from these estimates due to such factors as changes in consumption patterns, sales or impairments of emission allowances or other intangible assets, delays in the in-service dates of wind assets, additional intangible acquisitions and other events.

(in millions)			2014			2015			2016			2017			2018
Duke Energy		$	43		$	19		$	17		$	16		$	16
Progress Energy			4			3			2			1			1
Duke Energy Progress			1			―			―			―			―
Duke Energy Florida			3			3			2			1			1
Duke Energy Ohio			11			9			9			9			9
Duke Energy Indiana			22			1			1			1			1

Investments_in_Unconsolidated_

Investments in Unconsolidated Affiliates	12 Months Ended
Investments in Unconsolidated Affiliates	Dec. 31, 2013
Investments In Unconsolidated Affiliates [Abstract]	'
Investment in Unconsolidated Affiliates	'
	12. INVESTMENTS IN UNCONSOLIDATED AFFILIATES
	EQUITY METHOD INVESTMENTS
	Investments in domestic and international affiliates that are not controlled by Duke Energy, but over which it has significant influence, are accounted for using the equity method. As of December 31, 2013 and 2012, the carrying amount of investments in affiliates with carrying amounts greater than zero approximated the amount of underlying equity in net assets.
	The following table presents Duke Energy's investments in unconsolidated affiliates accounted for under the equity method, as well as the respective equity in earnings, by segment.

		Years Ended December 31,
		2013				2012				2011
	(in millions)	Investments		Equity in earnings		Investments		Equity in earnings		Equity in earnings
	Regulated Utilities	$	4	$	-1	$	5	$	-5	$	—
	International Energy		82		110		81		134		145
	Commercial Power		252		7		219		14		6
	Other		52		6		178		5		9
	Total	$	390	$	122	$	483	$	148	$	160
	During the years ended December 31, 2013, 2012 and 2011, Duke Energy received distributions from equity investments of $144 million, $183 million and $149 million, respectively, which are included in Other assets within Cash Flows from Operating Activities on the Consolidated Statements of Cash Flows.
	Significant investments in affiliates accounted for under the equity method are discussed below.
	International Energy
	Duke Energy owns a 25 percent indirect interest in NMC, which owns and operates a methanol and MTBE business in Jubail, Saudi Arabia.
	Commercial Power
	Investments accounted for under the equity method primarily consist of Duke Energy's approximate 50 percent ownership interest in the five Catamount Sweetwater, LLC wind farm projects (Phase I-V), INDU Solar Holdings, LLC and DS Cornerstone, LLC. All of these entities own solar or wind power projects in the United States. Duke Energy also owns a 50 percent interest in Duke American Transmission Co., LLC which builds, owns and operates electric transmission facilities in North America.
	Other
	As of December 31, 2012, investments accounted for under the equity method primarily included a 50 percent ownership interest in DukeNet, which owns and operates telecommunications businesses. On December 31, 2013, Duke Energy completed the sale of its ownership interest in DukeNet to Time Warner Cable, Inc. After retiring existing DukeNet debt and payment of transactions expenses, Duke Energy received $215 million in cash proceeds and recorded a $105 million pretax gain in the fourth quarter of 2013.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	13. 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 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 Consolidated Statements of Operations and Comprehensive Income are presented in the following table.

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 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 for more information regarding money pool. The net impact of these transactions was not material for the years ended December 31, 2013, 2012 and 2011 for the Subsidiary Registrants.
	As discussed in Note 17, certain trade receivables have been sold by Duke Energy Ohio and Duke Energy Indiana to CRC, an affiliate 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 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 DECAM enters are accounted for as undesignated contracts or NPNS. Consequently, mark-to-market impacts of intercompany contracts with, and sales of power to, nonregulated entities are reflected in Duke Energy Ohio's Consolidated Statements of Operations and Comprehensive Income. These amounts totaled net expense of $6 million and net revenue of $24 million and $18 million, respectively, for the years ended December 31, 2013, 2012 and 2011. 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 payable of $43 million and $79 million, respectively, as of December 31, 2013 and 2012. This amount is recorded in Notes payable to affiliated companies on Duke Energy Ohio's Consolidated Balance Sheets.

Derivatives_and_Hedging

Derivatives and Hedging	12 Months Ended
Derivatives and Hedging	Dec. 31, 2013
Risk Management, Derivative Instruments And Hedging Activities [Abstract]	'
Derivatives and Hedging	'
	14. DERIVATIVES AND HEDGING
	The Duke Energy Registrants use commodity and interest rate contracts to manage commodity price and interest rate risks. The primary use of energy commodity derivatives is to hedge the generation portfolio against changes in the prices of electricity and natural gas. Interest rate swaps are used to manage interest rate risk associated with borrowings.
	All derivative instruments not identified as NPNS are recorded at fair value as assets or liabilities on the Consolidated Balance Sheets. Cash collateral related to derivative instruments executed under master netting agreement is offset against the collateralized derivatives on the balance sheet.
	Changes in the fair value of derivative agreements that either do not qualify for or have not been designated as hedges are reflected in current earnings or as regulatory assets or liabilities.
	Commodity Price Risk
	The Duke Energy Registrants are exposed to the impact of changes in the future prices of electricity, coal, and natural gas. Exposure to commodity price risk is influenced by a number of factors including the term of contracts, the liquidity of markets, and delivery locations.
	Commodity Fair Value and Cash Flow Hedges
	At December 31, 2013, there were no open commodity derivative instruments designated as hedges.
	Undesignated Contracts
	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 2018.
	Duke Energy Carolinas and Duke Energy Progress have entered into firm power sale agreements, which are accounted for as derivatives, as part of the Interim FERC Mitigation in connection with Duke Energy's merger with Progress Energy. See Note 2 for further information. Duke Energy Carolinas' undesignated contracts are primarily associated with forward sales and purchases of electricity. Duke Energy Progress' and Duke Energy Florida's undesignated contracts are primarily associated with forward purchases of natural gas. Duke Energy Ohio's undesignated contracts are primarily associated with forward sales and purchases of electricity, coal, and natural gas. Duke Energy Indiana's undesignated contracts are primarily associated with forward purchases and sales of electricity and financial transmission rights.
	Volumes
	The tables show information relating to the volume of the outstanding commodity derivatives. Amounts disclosed represent the notional volumes of commodity contracts excluding NPNS. 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.

			31-Dec-13
			Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Electricity (Gigawatt-hours)^(a)		71,466		1,205		925		925		―		69,362		203
	Natural gas (millions of decatherms)		636		―		363		141		222		274		―

			31-Dec-12
			Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Electricity (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 risk is managed by limiting variable-rate exposures 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. Pretax gains or losses recognized from inception to termination of the hedges are 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.

			31-Dec-13						31-Dec-12
	(in millions)		Duke Energy			Duke Energy Ohio			Duke Energy			Progress Energy			Duke Energy Progress		Duke Energy Ohio		Duke Energy Indiana
	Cash flow hedges^(a)		$	798		$	―		$	1,047		$	―		$	―	$	―	$	―
	Undesignated contracts			34			27			290			50			50		27		200
	Fair value hedges			―			―			250			―			―		250		―
		Total notional amount	$	832		$	27		$	1,587		$	50		$	50	$	277	$	200

	(a)	Duke Energy includes amounts related to non-recourse variable rate long-term debt of VIEs of $584 million at December 31, 2013 and $620 million at December 31, 2012.

	Duke Energy
	The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.


			December 31,
			2013						2012
	(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			27			―			7			―
	Current liabilities: Other			―			18			―			81
	Deferred credits and other liabilities: other			―			4			―			35
	Total Derivatives Designated as Hedging Instruments			27			23			9			119
	Derivatives Not Designated as Hedging Instruments
	Commodity contracts
	Current assets: other			201			158			41			2
	Investments and other assets: other			215			131			106			50
	Current liabilities: other			13			153			106			407
	Deferred credits and other liabilities: other			5			166			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			434			613			255			798
Total Derivatives		$	461		$	636		$	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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	214		$	233			$	322		$	299
Gross amounts offset			-179			-138				-192			-155
Net amount subject to master netting			35			95				130			144
Amounts not subject to master netting			―			14				4			11
Net amounts recognized on the Consolidated Balance Sheet		$	35		$	109			$	134		$	155

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
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 Consolidated Balance Sheet		$	35		$	61			$	417		$	259

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

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations where such gains and losses are included when reclassified from AOCI.

		Years Ended December 31,
(in millions)		2013			2012			2011
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts^(a)		$	79		$	-23		$	-88
Commodity contracts			1			1			―
Total Pretax Gains (Losses) Recorded in AOCI		$	80		$	-22		$	-88
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense		$	-2		$	2		$	-5
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	-2		$	2		$	-5

(a)	Reclassified to earnings as interest expense over the term of the related debt.

There was no hedge ineffectiveness during the years ended December 31, 2013, 2012 and 2011, and no gains or losses were excluded from the assessment of hedge effectiveness during the same periods.
At December 31, 2013, and December 31, 2012, $59 million and $151 million, respectively, of pretax deferred net losses interest rate cash flow hedges were included in AOCI. A $4 million pretax gain is expected to be recognized in earnings during the next 12 months as interest expense.
The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations or the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric		$	11		$	-23		$	―
Revenue: Nonregulated electric, natural gas and other			43			38			-59
Other income and expenses			―			-2			―
Fuel used in electric generation and purchased power-regulated			-200			-194			―
Fuel used in electric generation and purchased power - nonregulated			-100			2			-1
Interest rate contracts
Interest expense			-18			-8			―
Total Pretax (Losses) Gains Recognized in Earnings		$	-264		$	-187		$	-60
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(a)
Regulatory assets		$	10		$	-2		$	-1
Regulatory liabilities			15			36			17
Interest rate contracts^(b)
Regulatory assets			55			10			-165
Regulatory liabilities			―			―			-60
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	80		$	44		$	-209

(a)	Reclassified to earnings to match recovery through the fuel clause.
(b)	Reclassified to earnings as interest expense over the term of the related debt.

Duke Energy Carolinas
The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

		December 31,
		2013						2012
(in millions)		Asset			Liability			Asset			Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current liabilities: other			―			1			―			6
Deferred credits and other liabilities: other			―			1			―			6
Total Derivatives Not Designated as Hedging Instruments			―			2			―			12
Total Derivatives		$	―		$	2		$	―		$	12

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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Amounts not subject to master netting		$	―		$	―			$	1		$	1
Net amounts recognized on the Consolidated Balance Sheet		$	―		$	―			$	1		$	1

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

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

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income where such gains and losses are included when reclassified from AOCI.

Losses on cash flow hedges reclassified at Duke Energy Carolinas during the year ended December 31, 2013 and 2012 were not material.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense		$	-3		$	-3		$	-5
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	-3		$	-3		$	-5

For the years ended December 31, 2013, Duke Energy Carolinas had $23 million of pretax deferred net losses on settled interest rate cash flow hedges remaining in AOCI. A $5 million pretax gain is expected to be recognized in earnings during the next 12 months as interest expense.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations or the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric		$	-12		$	-12		$	―
Total Pretax (Losses) Gains Recognized in Earnings		$	-12		$	-12		$	―
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Interest rate contracts
Regulatory assets		$	―		$	―		$	-94
Regulatory liabilities			―			―			-60
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	―		$	―		$	-154

Progress Energy
The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

		December 31,
		2013						2012
(in millions)		Asset			Liability			Asset			Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current liabilities: other		$	―		$	1		$	―		$	2
Deferred credits and other liabilities: other			―			4			―			1
Total Derivatives Designated as Hedging Instruments			―			5			―			3
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current assets: other			3			2			3			―
Investments and other assets: other			2			1			8			―
Current liabilities: other			11			105			―			231
Deferred credits and other liabilities: other			4			91			―			195
Interest rate contracts
Current liabilities: other			―			―			―			11
Total Derivatives Not Designated as Hedging Instruments			20			199			11			437
Total Derivatives		$	20		$	204		$	11		$	440

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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	15		$	5			$	107		$	93
Gross amounts offset			-13			-4				-17			-10
Net amount subject to master netting			2			1				90			83
Amounts not subject to master netting			―			―				―			4
Net amounts recognized on the Consolidated Balance Sheet		$	2		$	1			$	90		$	87

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

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

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheet where such gains and losses are included when reclassified from AOCI.

		Years Ended December 31,
(in millions)		2013			2012			2011
Pretax Gains (Losses) Recorded in AOCI
Commodity contracts		$	1		$	1		$	-3
Interest rate contracts^(a)			―			-11			-141
Total Pretax Gains (Losses) Recorded in AOCI		$	1		$	-10		$	-144
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense		$	―		$	-14		$	-13
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	―		$	-14		$	-13
Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets or Liabilities^(b)
Interest rate contracts
Regulatory assets		$	―		$	-159		$	―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	―		$	-159		$	―

(a)	Reclassified to earnings as interest expense over the term of the related debt.
(b)	Effective with the merger, Progress Energy no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

There was no hedge ineffectiveness during the years ended December 31, 2013, 2012, and 2011, and no gains or losses have been excluded from the assessment of hedge effectiveness during the same periods.
At December 31, 2013, and 2012, $61 million and $65 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 interest expense.
The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues		$	11		$	-11		$	1
Fuel used in electric generation and purchased power			-200			-454			-297
Other income and expenses, net			―			7			-59
Interest rate contracts
Interest expense			-17			-8			―
Total Pretax (Losses) Gains Recognized in Earnings		$	-206		$	-466		$	-355
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(a)
Regulatory assets		$	10		$	-171		$	-502
Interest rate contracts^(b)
Regulatory assets			18			6			―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	28		$	-165		$	-502

(a)	Reclassified to earnings to match recovery through the fuel clause.
(b)	Reclassified to earnings as interest expense over the term of the related debt.

Duke Energy Progress
The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

		December 31,
		2013						2012
(in millions)		Asset			Liability			Asset			Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current liabilities: other		$	―		$	1		$	―		$	1
Deferred credits and other liabilities: other			―			―			―			1
Total Derivatives Designated as Hedging Instruments			―			1			―			2
Derivatives Not Designated as Hedging Instruments
Commodity contracts^(a)
Current assets: other			―			―			1			―
Investments and other assets: other			2			1			1			―
Current liabilities: other			2			40			―			85
Deferred credits and other liabilities: other			2			29			―			68
Interest rate contracts
Current liabilities: other			―			―			―			11
Total Derivatives Not Designated as Hedging Instruments			6			70			2			164
Total Derivatives		$	6		$	71		$	2		$	166

(a)	Substantially all of these contracts are recorded as regulatory assets or liabilities.

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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	3		$	3			$	41		$	30
Gross amounts offset			-3			-3				-3			-3
Net amount subject to master netting			―			―				38			27
Net amounts recognized on the Consolidated Balance Sheet		$	―		$	―			$	38		$	27

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	1		$	1			$	97		$	69
Gross amounts offset			―			―				-2			-7
Net amounts subject to master netting			1			1				95			62
Net amounts recognized on the Consolidated Balance Sheet		$	1		$	1			$	95		$	62

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

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheets in which such gains and losses are included when reclassified from AOCI.

		Years Ended December 31,
(in millions)		2013			2012			2011
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts^(a)		$	―		$	-7		$	-70
Total Pretax Gains (Losses) Recorded in AOCI		$	―		$	-7		$	-70
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense		$	―		$	-5		$	-7
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	―		$	-5		$	-7
Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets or Liabilities^(b)
Interest rate contracts
Regulatory assets		$	―		$	-117		$	―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	―		$	-117		$	―

(a)	Reclassified to earnings as interest expense over the term of the related debt.
(b)	Effective with the merger, Duke Energy Progress no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

There was no hedge ineffectiveness during the years ended December 31, 2013, 2012 and 2011, and no gains or losses have been excluded from the assessment of hedge effectiveness during the same periods.
The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues		$	11		$	-11		$	1
Fuel used in electric generation and purchased power			-71			-115			-60
Interest rate contracts
Interest expense			-13			-6			―
Total Pretax (Losses) Gains Recognized in Earnings		$	-73		$	-132		$	-59
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(a)
Regulatory assets		$	-6		$	-55		$	-140
Interest rate contracts^(b)
Regulatory assets			13			6			―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	7		$	-49		$	-140

(a)	Reclassified to earnings to match recovery through the fuel clause.
(b)	Reclassified to earnings as interest expense over the term of the related debt.

Duke Energy Florida
The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

		December 31,
		2013						2012
(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			3			2			2			―
Investments and other assets: other			―			―			7			―
Current liabilities: other			9			64			―			146
Deferred credits and other liabilities: other			2			63			―			123
Total Derivatives Not Designated as Hedging Instruments			14			129			9			269
Total Derivatives		$	14		$	129		$	9		$	270

(a)	Substantially all of these contracts are recorded as regulatory assets or liabilities.

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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	12		$	2			$	66		$	63
Gross amounts offset			-10			-2				-15			-7
Net amount subject to master netting			2			―				51			56
Net amounts recognized on the Consolidated Balance Sheet		$	2		$	―			$	51		$	56

		31-Dec-12
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	2		$	7			$	147		$	123
Gross amounts offset			―			―				-20			-29
Net amounts subject to master netting			2			7				127			94
Net amounts recognized on the Consolidated Balance Sheet		$	2		$	7			$	127		$	94

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

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheets in which such gains and losses are included when reclassified from AOCI.

		Years Ended December 31,
(in millions)		2013			2012			2011
Pretax Gains (Losses) Recorded in AOCI
Commodity contracts		$	1		$	1		$	-3
Interest rate contracts^(a)			―			-2			-35
Total Pretax Gains (Losses) Recorded in AOCI		$	1		$	-1		$	-38
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense		$	―		$	-2		$	-1
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	―		$	-2		$	-1
Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets^(b)
Interest rate contracts
Regulatory assets		$	―		$	-42		$	―
Total Pretax Gains (Losses) Reclassified from AOCI to Regulatory Assets		$	―		$	-42		$	―

(a)	Reclassified to earnings as interest expense over the term of the related debt.
(b)	Effective with the merger, Duke Energy Florida no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

There was no hedge ineffectiveness during the years ended December 31,2013, 2012 and 2011, and no gains or losses have been excluded from the assessment of hedge effectiveness during the same periods.
The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Fuel used in electric generation and purchased power		$	-129		$	-339		$	-237
Interest rate contracts
Interest expense			-5			-2			―
Total Pretax (Losses) Gains Recognized in Earnings		$	-134		$	-341		$	-237
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(a)
Regulatory assets		$	16		$	-116		$	-362
Interest rate contracts
Regulatory assets			5			―			―
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	21		$	-116		$	-362

(a)	Reclassified to earnings to match recovery through the fuel clause.

Duke Energy Ohio
The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.

		December 31,
		2013						2012
(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			186			163			31			4
Investments and other assets: other			202			130			81			51
Current liabilities: other			1			36			106			132
Deferred credits and other liabilities: other			2			56			―			4
Interest rate contracts
Current liabilities: other			―			1			―			1
Deferred credits and other liabilities: other			―			4			―			7
Total Derivatives Not Designated as Hedging Instruments			391			390			218			199
Total Derivatives		$	391		$	390		$	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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.


		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	186		$	205			$	199		$	186
Gross amounts offset			-165			-132				-173			-143
Net amount subject to master netting			21			73				26			43
Amounts not subject to master netting			―			―				1			4
Net amounts recognized on the Consolidated Balance Sheet		$	21		$	73			$	27		$	47

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

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

There were no gains or losses on cash flow hedges recorded or reclassified at Duke Energy Ohio for the years ended December 31, 2013 and 2012, respectively. There was an immaterial amount of losses on cash flow hedges reclassified at Duke Energy Ohio for the year ended December 31, 2011.
The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Statements of Operations and Comprehensive Income or the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Nonregulated electric, natural gas and other		$	44		$	76		$	-26
Fuel used in electric generation and purchased power - nonregulated			-100			2			-1
Interest rate contracts
Interest expense			-1			-1			-1
Total Pretax (Losses) Gains Recognized in Earnings		$	-57		$	77		$	-28
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets		$	―		$	2		$	1
Regulatory liabilities			―			-1			―
Interest rate contracts
Regulatory assets			4			―			-4
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	4		$	1		$	-3

Duke Energy Indiana
The following table shows the fair value of derivatives and the line items in the Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Consolidated Balance Sheets, the fair values presented below are shown gross and cash collateral on the derivatives has not been netted against the fair values shown.


		December 31,
		2013						2012
(in millions)		Asset			Liability			Asset			Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current assets: other		$	12		$	―		$	10		$	―
Interest rate contracts
Current liabilities: other			―			―			―			63
Total Derivatives Not Designated as Hedging Instruments			12			―			10			63
Total Derivatives		$	12		$	―		$	10		$	63

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 financial position. The amounts shown were calculated by counterparty. Accounts receivable or accounts payable may also be available to offset exposures in the event of bankruptcy. These amounts are not included in the tables below.

		31-Dec-13
		Derivative Assets							Derivative Liabilities
(in millions)		Current^(a)			Non-Current^(b)				Current^(c)			Non-Current^(d)
Gross amounts recognized		$	12		$	―			$	―		$	―
Gross amounts offset			-1			―				―			―
Net amount subject to master netting			11			―				―			―
Net amounts recognized on the Consolidated Balance Sheet		$	11		$	―			$	―		$	―

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

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

The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income where such gains and losses are included when reclassified from AOCI.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense		$	3		$	3		$	2
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	3		$	3		$	2

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Consolidated Balance Sheets where the pretax gains and losses were reported.

		Years Ended December 31,
(in millions)		2013			2012			2011
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue, regulated electric		$	1		$	―		$	―
Total Pretax (Losses) Gains Recognized in Earnings		$	1		$	―		$	―
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts^(a)
Regulatory assets		$	―		$	2		$	-2
Regulatory liabilities			16			35			17
Interest rate contracts^(b)
Regulatory assets			34			4			-67
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	50		$	41		$	-52

(a)	Reclassified to earnings to match recovery through the fuel clause.
(b)	Reclassified to earnings as interest expense over the term of the related debt.

CREDIT RISK
Certain 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.

		31-Dec-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		$	525		$	168		$	60		$	108		$	355
Fair value of collateral already posted			135			10			―			10			125
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered			205			158			60			98			47

		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 derivatives. For amounts to be netted, the derivative must be executed with the same counterparty under the same master netting agreement. Amounts disclosed 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.

		December 31,
		2013						2012
(in millions)		Receivables			Payables			Receivables			Payables
Duke Energy
Amounts offset against net derivative positions		$	30		$	―		$	73		$	―
Amounts not offset against net derivative positions			122			―			93			―
Progress Energy
Amounts offset against net derivative positions		$	10		$	―		$	58		$	―
Amounts not offset against net derivative positions			―			―			1			―
Duke Energy Progress
Amounts offset against net derivative positions		$	―		$	―		$	9		$	―
Amounts not offset against net derivative positions			―			―			―			―
Duke Energy Florida
Amounts offset against net derivative positions		$	10		$	―		$	49		$	―
Amounts not offset against net derivative positions			―			―			1			―
Duke Energy Ohio
Amounts offset against net derivative positions		$	19			―		$	15		$	―
Amounts not offset against net derivative positions			115		$	―			92			―
Duke Energy Indiana
Amounts offset against net derivative positions			―			1			―			―
Amounts not offset against net derivative positions		$	1		$	―		$	―		$	―

Investments_in_Debt_and_Equity

Investments in Debt and Equity Securities	12 Months Ended
Investments in Debt and Equity Securities	Dec. 31, 2013
Investments In Debt And Equity Securities [Abstract]	'
Investments In Debt And Equity Securities	'
	15. 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.
	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. The fair value of these investments was $18 million as of December 31, 2013 and $33 million as of December 31, 2012.
	AVAILABLE-FOR-SALE SECURITIES
	All other investments in debt and equity securities are classified as available-for-sale securities.
	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 Progress, Duke Energy Florida and Duke Energy Indiana related to OPEB plans, (iii) Duke Energy's captive insurance investment portfolio, and (iv) Duke Energy's foreign operations investment 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 Consolidated Balance Sheets and are available for current operations of Duke Energy's foreign business. The fair value of these investments was $44 million as of December 31, 2013 and $333 million as of December 31, 2012.
	Duke Energy classifies all other investments in debt and equity securities as non-current, 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 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 realized and 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 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 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 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 December 31, 2013 and 2012. There were no other-than-temporary impairments for debt or equity securities as of December 31, 2013 and 2012. Other available-for-sale securities were reflected as a component of other comprehensive income in 2013 and 2012.

	DUKE ENERGY

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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		$	—		$	—		$	110		$	—		$	—		$	105
	Equity securities			1,813			10			3,579			1,132			19			2,837
	Corporate debt securities			8			6			400			21			1			338
	Municipal bonds			2			6			160			12			1			194
	U.S. government bonds			7			12			730			24			1			625
	Other debt securities			22			2			154			10			1			164
	Total NDTF			1,852			36			5,133			1,199			23			4,263
	Other Investments
	Cash and cash equivalents			—			—			21			—			—			17
	Equity securities			29			—			91			10			—			63
	Corporate debt securities			1			1			99			2			—			381
	Municipal bonds			2			2			79			4			1			70
	U.S. government bonds			—			—			17			—			—			23
	Other debt securities			—			8			111			1			6			115
	Total Other Investments^(a)			32			11			418			17			7			669
	Total Investments		$	1,884		$	47		$	5,551		$	1,216		$	30		$	4,932

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

	The table below summarizes the maturity date for debt securities.

	(in millions)		31-Dec-13
	Due in one year or less		$	89
	Due after one through five years			431
	Due after five through 10 years			426
	Due after 10 years			804
	Total		$	1,750

	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.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Realized gains		$	209		$	117		$	79
	Realized losses			65			19			37

	DUKE ENERGY CAROLINAS

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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		$	―		$	―		$	42		$	―		$	―		$	40
Equity securities			974			6			1,964			600			5			1,592
Corporate debt securities			5			5			274			11			1			250
Municipal bonds			―			2			54			2			―			40
U.S. government bonds			3			7			354			10			―			304
Other debt securities			22			2			146			9			2			135
Total NDTF			1,004			22			2,834			632			8			2,361
Other Investments
Other debt securities			―			1			3			―			1			3
Total Other Investments^(a)			―			1			3			―			1			3
Total Investments		$	1,004		$	23		$	2,837		$	632		$	9		$	2,364

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

The table below summarizes the maturity date for debt securities.

(in millions)		31-Dec-13
Due in one year or less		$	18
Due after one through five years			167
Due after five through 10 years			239
Due after 10 years			407
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.

		Years Ended December 31,
(in millions)		2013			2012			2011
Realized gains		$	115		$	89		$	71
Realized losses			12			6			35

PROGRESS ENERGY

The following table presents the estimated fair value of investments in available-for-sale securities for Progress Energy.

		31-Dec-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		$	―		$	―		$	68		$	―		$	―		$	65
Equity securities			839			4			1,615			532			14			1,245
Corporate debt securities			3			1			126			9			―			89
Municipal bonds			2			4			106			11			1			154
U.S. government bonds			4			5			376			14			―			321
Other debt securities			―			―			8			1			―			28
Total NDTF			848			14			2,299			567			15			1,902
Other Investments
Cash and cash equivalents			―			―			20			―			―			17
Municipal bonds			1			―			39			3			―			40
Total Other Investments^(a)			1			―			59			3			―			57
Total Investments		$	849		$	14		$	2,358		$	570		$	15		$	1,959

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

The table below summarizes the maturity date for debt securities.

(in millions)		31-Dec-13
Due in one year or less		$	12
Due after one through five years			206
Due after five through 10 years			131
Due after 10 years			306
Total		$	655

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.

		Years Ended December 31,
(in millions)		2013			2012			2011
Realized gains		$	90		$	34		$	30
Realized losses			46			18			33

DUKE ENERGY PROGRESS

The following table presents the estimated fair value of investments in available-for-sale securities.

		31-Dec-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		$	―		$	―		$	48		$	―		$	―		$	55
Equity securities			535			3			1,069			337			11			811
Corporate debt securities			3			1			80			8			―			78
Municipal bonds			2			4			104			4			―			80
U.S. government bonds			4			3			232			13			―			241
Other debt securities			―			―			5			1			―			10
Total NDTF			544			11			1,538			363			11			1,275
Other Investments
Cash and cash equivalents			―			―			2			―			―			3
Total Other Investments^(a)			―			―			2			―			―			3
Total Investments		$	544		$	11		$	1,540		$	363		$	11		$	1,278

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

The table below summarizes the maturity date for debt securities.

(in millions)		31-Dec-13
Due in one year or less		$	7
Due after one through five years			122
Due after five through 10 years			89
Due after 10 years			203
Total		$	421

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.

		Years Ended December 31,
(in millions)		2013			2012			2011
Realized gains		$	58		$	21		$	13
Realized losses			26			8			16

DUKE ENERGY FLORIDA

The following table presents the estimated fair value of investments in available-for-sale securities.

		31-Dec-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		$	―		$	―		$	20		$	―		$	―		$	10
Equity securities			304			1			546			194			4			434
Corporate debt securities			―			―			46			1			―			11
Municipal bonds			―			―			2			7			―			74
U.S. government bonds			―			2			144			1			―			80
Other debt securities			―			―			3			1			―			18
Total NDTF			304			3			761			204			4			627
Other Investments
Cash and cash equivalents			―			―			3			―			―			1
Municipal bonds			1			―			39			3			―			40
Total Other Investments^(a)			1			―			42			3			―			41
Total Investments		$	305		$	3		$	803		$	207		$	4		$	668

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

The table below summarizes the maturity date for debt securities.

(in millions)		31-Dec-13
Due in one year or less		$	5
Due after one through five years			84
Due after five through 10 years			42
Due after 10 years			103
Total		$	234

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.

			Years Ended December 31,
(in millions)			2013			2012			2011
Realized gains			$	32		$	13		$	17
Realized losses				20			9			17

DUKE ENERGY INDIANA

The following table presents the estimated fair value of investments in available-for-sale securities.

		31-Dec-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
Cash and cash equivalents		$	―		$	―		$	1		$	―		$	―		$	―
Equity securities			24			―			65			9			―			50
Municipal bonds			―			1			28			1			―			28
Total Other Investments^(a)			24			1			94			10			―			78
Total Investments		$	24		$	1		$	94		$	10		$	―		$	78

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

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

(in millions)		31-Dec-13
Due in one year or less		$	1
Due after one through five years			21
Due after five through 10 years			4
Due after 10 years			2
Total		$	28

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Dec. 31, 2013													Dec. 31, 2012
Fair Value Of Financial Assets And Liabilities [Abstract]	'													'
Fair Value Measurements	'													'
	16. FAIR VALUE MEASUREMENTS
	Fair value is the exchange price to sell an asset or transfer a liability in an orderly transaction between market participants at the measurement date. The fair value definition focuses on an exit price versus the acquisition cost. Fair value measurements use 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 may be readily observable, corroborated by market data, or generally unobservable. Valuation techniques maximize the 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.														31-Dec-12
	Fair value measurements are classified in three levels based on the fair value hierarchy:													Investment Type	Fair Value (in millions)		Valuation Technique	Unobservable Input	Range
	Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities that the reporting entity can access at the measurement date. An active market is one in which transactions for an asset or liability occur with sufficient frequency and volume to provide ongoing pricing information.													Duke Energy
	Level 2 – A fair value measurement utilizing inputs other than quoted prices included in Level 1 that are observable, either directly or indirectly, for an asset or liability. Inputs include (i) quoted prices for similar assets or liabilities in active markets, (ii) quoted prices for identical or similar assets or liabilities in markets that are not active, (iii) and 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, and credit spreads. 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.													Natural gas contracts	$	-53	Discounted cash flow	Forward natural gas curves - price per MMBtu	$	2.33	$	9.99
	Level 3 – Any fair value measurement which includes unobservable inputs 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 measurements may include longer-term instruments that extend into periods in which observable inputs are not available.													FERC mitigation power sale agreements		-23	Discounted cash flow	Forward electricity curves - price per MWh		25.83	-	48.69
	The fair value accounting guidance permits entities to elect to measure certain financial instruments that are not required to be accounted for at fair value, such as equity method investments or the company's own debt, at fair value. The Duke Energy Registrants have not elected to record any of these items at fair value.													FTRs		11	RTO auction pricing	FTR price - per MWh		23.63	-	39.22
	Transfers between levels represent assets or liabilities that were previously (i) categorized at a higher level for which the inputs to the estimate became less observable or (ii) classified at a lower level for which the inputs 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 no transfers between levels 1 and 2 during the years ended December 31, 2013 and 2012. Transfers out of Level 3 during the year ended December 31, 2013 are the result of forward commodity prices becoming observable due to the passage of time.													Electricity contracts		-8	Discounted cash flow	Forward electricity curves - price per MWh		24.82	-	77.96
	Valuation methods of the primary fair value measurements disclosed below are as follows.													Capacity contracts		-3	Discounted cash flow	Forward capacity curves - price per MW day		95.16	-	105.36
	Investments in equity securities													Capacity option contracts		3	Discounted cash flow	Forward capacity option curves - price per MW day		4.68	-	77.96
	The majority of investments in equity securities are valued using Level 1 measurements. Investments in equity securities are typically valued at the closing price in the principal active market as of the last business day of the quarter. 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. There was no after-hours market activity that was required to be reflected in the reported fair value measurements. Investments in equity securities that are Level 2 or 3 are typically ownership interests in commingled investment funds.													Reserves		-12		Bid-ask spreads, implied volatility, probability of default
	Investments in debt securities													Total Level 3 derivatives	$	-85
	Most investments in debt securities are valued using Level 2 measurements because the valuations uses 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. If the market for a particular fixed income security is relatively inactive or illiquid, the measurement is Level 3.													Duke Energy Carolinas
	Commodity derivatives													FERC mitigation power sale agreements	$	-12	Discounted cash flow	Forward electricity curves - price per MWh	$	25.83	-	48.69
	Commodity derivatives with clearinghouses are classified as Level 1. Other commodity derivatives are primarily fair valued using internally developed discounted cash flow models which incorporate forward price, adjustments for liquidity (bid-ask spread) and credit or non-performance risk (after reflecting credit enhancements such as collateral), and are discounted to present value. Pricing inputs are derived from published exchange transaction prices and other observable data sources. In the absence of an active market, the last available price may be used. If forward price curves are not observable for the full term of the contract and the unobservable period had more than an insignificant impact on the valuation, the commodity derivative is classified as Level 3. In isolation, increases (decreases) in natural gas forward prices result in favorable (unfavorable) fair value adjustments for gas purchase contracts; and increases (decreases) in electricity forward prices 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 commodity contracts by a market participant price verification procedure. This procedure provides a comparison of internal forward commodity curves to market participant generated curves.													Progress Energy
	Interest rate derivatives													Natural gas contracts	$	-27	Discounted cash flow	Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
	Most over-the-counter interest rate contract derivatives are valued using financial models which utilize observable inputs for similar instruments and are classified as Level 2. Inputs include forward interest rate curves, notional amounts, interest rates and credit quality of the counterparties.													FERC mitigation power sale agreements		-11	Discounted cash flow	Forward electricity curves - price per MWh		25.83	-	48.69
	Goodwill and long-lived assets													Total Level 3 derivatives	$	-38
	See Note 11 for a discussion of the valuation of goodwill and long-lived assets.													Duke Energy Progress
	Duke Energy													Natural gas contracts	$	-27	Discounted cash flow	Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
	The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.													FERC mitigation power sale agreements		-11	Discounted cash flow	Forward electricity curves - price per MWh		25.83	-	48.69
														Total Level 3 derivatives	$	-38
			31-Dec-13											Duke Energy Ohio
	(in millions)		Total Fair Value			Level 1			Level 2			Level 3		FTRs	$	1	RTO auction pricing	FTR price - per MWh	$	27.17	$	39.22
	Nuclear decommissioning trust fund equity securities		$	3,579		$	3,495		$	57		$	27	Electricity contracts		-1	Discounted cash flow	Forward electricity curves - price per MWh		25.9	-	57.5
	Nuclear decommissioning trust fund debt securities			1,553			402			1,100			51	Natural gas contracts		5	Discounted cash flow	Forward natural gas curves - price per MMBtu		3.3	-	4.51
	Other trading and available-for-sale equity securities^(a)			102			91			11			―	Reserves		-11		Bid-ask spreads, implied volatility, probability of default
	Other trading and available-for-sale debt securities^(b)			333			36			277			20	Total Level 3 derivatives	$	-6
	Derivative assets^(a)			145			33			70			42	Duke Energy Indiana
		Total assets		5,712			4,057			1,515			140	FTRs	$	10	RTO auction pricing	FTR price - per MWh	$	23.63	$	35.43
	Derivative liabilities^(c)			-321			11			-303			-29
		Net assets	$	5,391		$	4,068		$	1,212		$	111


			31-Dec-12
	(in millions)		Total Fair Value			Level 1			Level 2			Level 3
	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^(a)			72			63			9			―
	Other trading and available-for-sale debt securities^(b)			631			40			562			29
	Derivative assets^(a)			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 Current Assets and Other within Investments and Other Assets on the Consolidated Balance Sheet.
	(b)	Included in Other within Investments and Other Assets and Short-term Investments on the Consolidated Balance Sheets.
	(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the 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.

			31-Dec-13
	(in millions)			Investments			Derivatives (net)			Total
	Balance at December 31, 2012			$	98		$	-85		$	13
	Total pretax realized or unrealized gains (losses) included in earnings^(a)				―			-42			-42
	Purchases, sales, issuances and settlements:
		Purchases			9			21			30
		Sales			-6			―			-6
		Issuances			―			11			11
		Settlements			-9			25			16
	Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				6			-3			3
	Transfers out of Level 3^(b)				―			86			86
	Balance at December 31, 2013			$	98		$	13		$	111
Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding			$	―		$	10		$	10

(a)	Amounts for derivatives are primarily included in Operating Revenues.
(b)	Transfers reflect derivative contracts becoming observable due to the passage of time.


		31-Dec-12
(in millions)			Investments			Derivatives (net)			Total
Balance at December 31, 2011			$	124		$	-39		$	85
Amounts acquired in Progress Energy Merger				―			-30			-30
Total pretax realized or unrealized gains (losses) included in earnings				―			8			8
Total pretax gains included in other comprehensive income				13			―			13
Purchases, sales, issuances and settlements:
	Purchases			14			22			36
	Sales			-2			―			-2
	Issuances			―			-15			-15
	Settlements			-55			-32			-87
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				4			1			5
Balance at December 31, 2012			$	98		$	-85		$	13


		31-Dec-11
(in millions)			Investments			Derivatives (net)			Total
Balance at December 31, 2010			$	165		$	-19		$	146
Total pretax realized or unrealized gains (losses) included in earnings				―			-14			-14
Total pretax gains included in other comprehensive income				12			―			12
Net purchases, sales, issuances and settlements:
	Purchases			8			8			16
	Sales			-3			―			-3
	Settlements			-16			-16			-32
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				-42			2			-40
Balance at December 31, 2011			$	124		$	-39		$	85

Duke Energy Carolinas
The following tables provide recorded balances for assets and liabilities measure at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

			31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities		$	1,964		$	1,879		$	58		$	27
Nuclear decommissioning trust fund debt securities			870			168			651			51
Other available-for-sale debt securities^(a)			3			-			-			3
	Total assets		2,837			2,047			709			81
Derivative liabilities^(b)			-2			―			―			-2
	Net assets	$	2,835		$	2,047		$	709		$	79


		31-Dec-12
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities		$	1,592		$	1,523		$	48		$	21
Nuclear decommissioning trust fund debt securities			762			155			559			48
Other available-for-sale debt securities^(a)			3			―			―			3
	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 Consolidated Balance Sheets.
(b)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheet.

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

		31-Dec-13
			Investments			Derivatives (net)			Total
Balance at December 31, 2012			$	72		$	-12		$	60
Purchases, sales, issuances and settlements:
	Purchases			9			―			9
	Sales			-6			―			-6
	Settlements			―			10			10
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				6			―			6
Balance at December 31, 2013			$	81		$	-2		$	79
Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding			$	―		$	-4		$	-4


		31-Dec-12
			Investments			Derivatives (net)			Total
Balance at December 31, 2011			$	65		$	―		$	65
Total pretax gains included in comprehensive income				2			―			2
Purchases, sales, issuances and settlements:
	Purchases			14			―			14
	Issuances			―			-14			-14
	Sales			-2			―			-2
	Settlements			-11			2			-9
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				4			―			4
Balance at December 31, 2012			$	72		$	-12		$	60


		31-Dec-11
(in millions)			Investments			Derivatives (net)			Total
Balance at December 31, 2010			$	59		$	―		$	59
Purchases, sales, issuances and settlements:
	Purchases			8			―			8
	Sales			-3			―			-3
Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				1			―			1
Balance at December 31, 2011			$	65		$	―		$	65

Progress Energy
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis end on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities		$	1,615		$	1,615		$	―		$	―
Nuclear decommissioning trust fund debt securities and other			677			233			444			―
Other trading and available-for-sale debt securities and other^(a)			58			19			39			―
Derivative assets^(b)			3			―			3			―
	Total assets		2,353			1,867			486			―
Derivative liabilities^(c)			-187			―			-187			―
	Net assets	$	2,166		$	1,867		$	299		$	―


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

The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

		Derivatives (net)
		Years Ended December 31,
(in millions)		2013			2012			2011
Balance at beginning of period		$	-38		$	-24		$	-36
Total pretax realized or unrealized gains included in earnings			―			1			―
Purchases, sales, issuances and settlements:
	Issuances		10			-16			―
	Settlements		―			4			―
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			-6			-3			-21
Transfers out of Level 3^(a)			34			―			33
Balance at end of period		$	―		$	-38		$	-24
Pretax amounts included in the Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding		$	11

(a)	Transfers reflect derivative contracts becoming observable due to the passage of time.

Duke Energy Progress
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 14 . See Note 15 for additional information related to investments by major security type.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities		$	1,069		$	1,069		$	―		$	―
Nuclear decommissioning trust fund debt securities and other			470			137			333			―
Other trading and available-for-sale debt securities and other^(a)			3			3			―			―
Derivative assets^(b)			1			―			1			―
	Total assets		1,543			1,209			334			―
Derivative liabilities^(c)			-66			―			-66			―
	Net assets	$	1,477		$	1,209		$	268		$	―


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

The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

		Derivatives (net)
		Years Ended December 31,
(in millions)		2013			2012			2011
Balance at beginning of period		$	-38		$	-24		$	-36
Total pretax realized or unrealized gains included in earnings			―			1			―
Purchases, sales, issuances and settlements:
	Issuances		10			-16			―
	Settlements		―			4			―
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			-6			-3			-20
Transfers out of Level 3^(a)			34			―			32
Balance at end of period		$	―		$	-38		$	-24
Pretax amounts included in the Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding		$	11

(a)	Transfers reflect derivative contracts becoming observable due to the passage of time.

Duke Energy Florida
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities		$	546		$	546		$	―		$	―
Nuclear decommissioning trust fund debt securities and other			214			96			118			―
Other trading and available-for-sale debt securities and other^(a)			40			2			38			―
Derivative assets^(b)			1			―			1			―
	Total assets		801			644			157			―
Derivative liabilities^(c)			-116			―			-116			―
	Net assets	$	685		$	644		$	41		$	―


		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^(b)			9			―			9			―
	Total assets		681			475			206			―
Derivative liabilities^(c)			-270			―			-270			―
	Net assets	$	411		$	475		$	-64		$	―

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

Duke Energy Ohio
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which are disclosed in Note 14.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Derivative assets^(a)		$	96		$	50		$	21		$	25
Derivative liabilities^(b)			-95			-1			-65			-29
	Net assets (liabilities)	$	1		$	49		$	-44		$	-4


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

The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

		Derivatives (net)
		Years Ended December 31,
(in millions)		2013			2012			2011
Balance at beginning of period		$	-6		$	-3		$	13
Total pretax realized or unrealized gains included in earnings^(a)			-42			-3			-4
Purchases, sales, issuances and settlements:
	Purchases		1			―			―
	Settlements		―			1			-14
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			―			-1			2
Transfers out of Level 3^(b)			43			―			―
Balance at end of period		$	-4		$	-6		$	-3

(a)	Amounts for derivative are primarily included in Operating Revenues.
(b)	Transfers reflect derivative contracts becoming observable due to the passage of time.

Duke Energy Indiana
The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 14. See Note 15 for additional information related to investments by major security type.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Available-for-sale equity securities^(a)		$	65		$	65		$	―		$	―
Available-for-sale debt securities^(a)			29			―			29			―
Derivative assets^(b)			12			―			―			12
	Net assets (liabilities)	$	106		$	65		$	29		$	12


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

The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

		Derivatives (net)
		Years Ended December 31,
(in millions)		2013			2012			2011
Balance at beginning of period		$	10		$	4		$	4
Total pretax realized or unrealized gains included in earnings^(a)			8			36			14
Purchases, sales, issuances and settlements:
	Purchases		20			―			8
	Sales		―			22			―
	Settlements		-30			-52			-21
Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			4			―			-1
Balance at end of period		$	12		$	10		$	4

(a)	Amounts in derivatives are primarily included in Operating Revenues.

QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS

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

		31-Dec-13
Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
Duke Energy
Natural gas contracts		$	-2		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.07	$	5.37
FERC mitigation power sale agreements			-2		Discounted cash flow		Forward electricity curves - price per MWh		25.79	-	52.38
Financial transmission rights (FTRs)			12		RTO auction pricing		FTR price - per Megawatt Hour (MWh)		-0.3	-	13.8
Electricity contracts			23		Discounted cash flow		Forward electricity curves - price per MWh		20.77	-	58.9
Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		30.4	-	165.1
Reserves			-22				Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives		$	13
Duke Energy Carolinas
FERC mitigation power sale agreements		$	-2		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	$	52.38
Duke Energy Ohio
Electricity contracts		$	18		Discounted cash flow		Forward electricity curves - price per MWh	$	20.77	$	58.9
Natural gas contracts			-2		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.07	-	5.37
Reserves			-20				Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives		$	-4
Duke Energy Indiana
FTRs		$	12		RTO auction pricing		FTR price - per MWh	$	-0.3	$	13.8

OTHER FAIR VALUE DISCLOSURES

The fair value and book value of long-term debt, including current maturities, is summarized in the following table. Estimates determined are not necessarily indicative of amounts that could have been settled in current markets. Fair value of long-term debt uses Level 2 measurements.

		31-Dec-13						31-Dec-12
(in millions)		Book Value			Fair Value			Book Value			Fair Value
Duke Energy		$	40,256		$	42,592		$	39,461		$	44,001
Duke Energy Carolinas			8,436			9,123			8,741			10,096
Progress Energy			14,115			15,234			14,428			16,563
Duke Energy Progress			5,235			5,323			4,840			5,277
Duke Energy Florida			4,886			5,408			5,320			6,222
Duke Energy Ohio			2,188			2,237			1,997			2,117
Duke Energy Indiana			3,796			4,171			3,702			4,268

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

Variable_Interest_Entities

Variable Interest Entities	12 Months Ended
Variable Interest Entities	Dec. 31, 2013
Variable Interest Entities [Abstract]	'
Variable Interest Entities	'
	17. 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. Other than the discussion below related to CRC, no financial support was provided to any of the VIEs during the years ended December 31, 2013, 2012 and 2011, or is expected to be provided in the future, that was not previously contractually required.
	CONSOLIDATED VIEs
	The table below shows the VIEs that Duke Energy, Duke Energy Carolinas and Duke Energy Progress consolidate and how these entities impact their respective Consolidated Balance Sheets.

			31-Dec-13
	(in millions)		DERF^(a)			DEPR^(b)			CRC			CinCapV			Renewables			Other			Total
	ASSETS
	Current Assets
	Restricted receivables of variable interest entities		$	673		$	416		$	595		$	17		$	18		$	―		$	1,719
	Other			―			―			―			10			89			2			101
	Investments and Other Assets
	Other			―			―			―			51			29			―			80
	Property, Plant and Equipment
	Property, plant and equipment, cost^(c)			―			―			―			―			1,662			18			1,680
	Accumulated depreciation and amortization			―			―			―			―			-170			-5			-175
	Regulatory Assets and Deferred Debits
	Other			1			1			―			―			34			―			36
	Total assets			674			417			595			78			1,662			15			3,441
	LIABILITIES AND EQUITY
	Current Liabilities
	Accounts payable			―			―			―			―			2			―			2
	Taxes accrued			―			―			―			―			10			―			10
	Current maturities of long-term debt			―			―			―			14			66			―			80
	Other			―			―			―			10			17			―			27
	Long-term Debt^(d)			400			300			325			34			907			―			1,966
	Deferred Credits and Other Liabilities
	Other			1			―			―			13			333			―			347
	Total liabilities			401			300			325			71			1,335			―			2,432
	Net assets of consolidated variable interest entities		$	273		$	117		$	270		$	7		$	327		$	15		$	1,009

	(a)	DERF is consolidated by Duke Energy Carolinas and Duke Energy.
	(b)	DEPR is consolidated by Duke Energy Progress and Duke Energy.
	(c)	Restricted as collateral for non-recourse debt of VIEs.
	(d)	Non-recourse to the general assets of Duke Energy.


			31-Dec-12
	(in millions)		DERF^(a)			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
	Other			―			―			62			14			2			78
	Property, Plant and Equipment
	Property, plant and equipment, cost^(b)			―			―			―			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
	Notes payable and commercial paper			―			312			―			―			―			312
	Taxes accrued			―			―			―			62			―			62
	Current maturities of long-term debt			―			―			13			459			―			472
	Other			―			―			4			25			―			29
	Long-term Debt^(c)			300			―			48			504			―			852
	Deferred Credits and Other Liabilities
	Deferred income taxes			―			―			―			154			―			154
	Asset retirement obligation			―			―			―			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

(a)	DERF is consolidated by Duke Energy Carolinas and Duke Energy.
(b)	Restricted as collateral for non-recourse debt of VIEs.
(c)	Non-recourse to the general assets of Duke Energy.

The obligations of these VIEs are non-recourse to Duke Energy, Duke Energy Carolinas and Duke Energy Progress. These entities have no requirement to provide liquidity to purchase assets of, or guarantee performance of these VIEs unless noted in the following paragraphs.
DERF
On a daily basis, Duke Energy Receivables Finance Company, LLC (DERF), a bankruptcy remote, special purpose subsidiary of Duke Energy Carolinas, buys certain accounts receivable arising from the sale of electricity and/or related services from Duke Energy Carolinas. DERF is a wholly owned limited liability company with a separate legal existence from its parent, and its assets are not generally available to creditors of Duke Energy Carolinas. DERF borrows $400 million under a credit facility to buy the receivables. Borrowing is limited to the amount of qualified receivables sold, which is expected to be in excess of $400 million. The receivables are used as collateral for commercial paper issued through third parties. The credit facility expires in October 2016 and is reflected on the Consolidated Balance Sheets as Long-term Debt. The secured credit facility was not structured to meet the criteria for sale accounting treatment under the accounting guidance for transfers and servicing of financial assets.
The most significant activity that impacts the economic performance of DERF is the decisions made to manage delinquent receivables. Duke Energy Carolinas consolidates DERF as it makes those decisions.
DEPR
On a daily basis, Duke Energy Progress Receivables Company, LLC (DEPR), a bankruptcy remote, special purpose subsidiary of Duke Energy Progress formed in 2013, buys certain accounts receivable arising from the sale of electricity and/or related services from Duke Energy Progress. DEPR is a wholly owned limited liability company with a separate legal existence from its parent, and its assets are not generally available to creditors of Duke Energy Progress. DEPR borrows $300 million under a credit facility to buy the receivables. Borrowing is limited to the amount of qualified receivables sold, which is expected to be in excess of $300 million. The receivables are used as collateral for commercial paper issued through third parties. The credit facility expires in December 2016 and is reflected on the Consolidated Balance Sheets as Long-term Debt. The secured credit facility was not structured to meet the criteria for sale accounting treatment under the accounting guidance for transfers and servicing of financial assets.
The most significant activity that impacts the economic performance of DEPR is the decisions made to manage delinquent receivables. Duke Energy Progress consolidates DEPR as it makes those decisions.
CRC
On a revolving basis, CRC buys certain accounts receivable arising from the sale of electricity and/or related services from Duke Energy Ohio and Duke Energy Indiana. 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. Proceeds Duke Energy Ohio and Duke Energy Indiana receive from the sale of receivables to CRC are typically 75 percent cash and 25 percent in the form of a subordinated note from CRC. The subordinated note is a retained interest in the receivables sold. Cash collections from the receivable are the sole source of funds to satisfy the related debt obligation. 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 years ended December 31, 2013 and 2012. For the year ended December 31, 2011, Duke Energy infused $6 million of equity to CRC to remedy net worth deficiencies. Borrowings fluctuate based on the amount of receivables sold. The credit facility expires in November 2016. The secured credit facility is reflected on the Consolidated Balance Sheets as Long-term Debt. 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, 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. Duke Energy consolidates CRC as it makes these decisions. Neither Duke Energy Ohio nor Duke Energy Indiana 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 the 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 guarantees for debt service and operations and maintenance reserves in support of debt financings. Assets are restricted and cannot be pledged as collateral or sold to third parties without prior approval of debt holders. 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. Duke Energy consolidated the entities as it makes all of these decisions.
NON-CONSOLIDATED VIEs
The tables below disclose VIEs the Duke Energy Registrants do not consolidate and how these entities impact the Duke Energy Registrants' respective Consolidated Balance Sheets.

		31-Dec-13
		Duke Energy
(in millions)		Renewables			Other			Total			Duke Energy Ohio^(a)			Duke Energy Indiana^(b)
Receivables		$	―		$	―		$	―		$	114		$	143
Investments in equity method unconsolidated affiliates			153			60			213			―			―
Intangibles			―			96			96			96			―
Investments and other assets			―			4			4			―			―
Total assets			153			160			313			210			143
Other current liabilities			―			3			3			―			―
Deferred credits and other liabilities			―			15			15			―			―
Total liabilities			―			18			18			―			―
Net assets		$	153		$	142		$	295		$	210		$	143

(a)	Reflects OVEC and retained interest in CRC.
(b)	Reflects retained interest in CRC.


		31-Dec-12
		Duke Energy
(in millions)		DukeNet			Renewables			FPC Capital I Trust^(c)		Other			Total			Duke Energy Ohio^(a)			Duke Energy Indiana^(b)
Receivables		$	―		$	―		$	―	$	―		$	―		$	97		$	116
Investments in equity method unconsolidated affiliates			118			147			―		27			292			―			―
Intangibles			―			―			―		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)	Reflects OVEC and retained interest in CRC.
(b)	Reflects retained interest in CRC.
(c)	The entire balance of Investments and other assets and $274 million of the Deferred Credits and Other Liabilities balance applies to Progress Energy.
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
Until December 31, 2013, Duke Energy owned a 50 percent ownership interest in DukeNet. DukeNet was considered a VIE because it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. The most significant activities that impacted DukeNet's economic performance relate to its business development and fiber optic capacity marketing and management activities. The power to direct these activities was jointly and equally shared by Duke Energy and the other joint venture partner.
On December 31, 2013, Duke Energy completed the sale of its ownership interest in DukeNet to Time Warner Cable, Inc. For more information on the sale of DukeNet, refer to Note 12.
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.
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 for the sole purpose of issuing $300 million of 7.10% Cumulative QUIPS due 2039, and using the 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. was formed for the sole purpose of providing financing to Duke Energy Florida. On February 1, 2013, Duke Energy redeemed the QUIPS and subsequently terminated the Trust.
Other
The most significant of the Other non-consolidated VIEs 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. This amount is included in the table above for Duke Energy and Duke Energy Ohio.
In addition, Duke Energy has guaranteed performance of certain entities in which it no longer has an equity interest.
CRC
See discussion under Consolidated VIEs for additional information related to CRC.
The subordinated notes held by Duke Energy Ohio and Duke Energy Indiana are stated at fair value and are classified within Receivables in their Consolidated Balance Sheets. 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 the retained interests using the acceptable yield method. This method generally approximates the stated rate on the notes since the allocated basis and the 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 that an other-than-temporary impairment has occurred.
Key assumptions used in estimating the fair value in 2013 and 2012 is 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
		December 31,						December 31,
(in millions)			2013		2012			2013			2012
Receivables sold		$	290		$	282		$	340		$	289
Less: Retained interests			114			97			143			116
Net receivables sold		$	176		$	185		$	197		$	173

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

			Duke Energy Ohio									Duke Energy Indiana
			Years Ended December 31,									Years Ended December 31,
(in millions)			2013			2012			2011			2013			2012			2011
Sales
Receivables sold			$	2,251		$	2,154		$	2,390		$	2,985		$	2,773		$	2,658
Loss recognized on sale				12			13			21			11			12			16
Cash Flows
Cash proceeds from receivables sold				2,220			2,172			2,474			2,944			2,784			2,674
Collection fees received				1			1			1			1			1			1
Return received on retained interests				5			5			12			6			7			13

Cash flows from the sale of receivables are reflected within Operating Activities on Duke Energy Ohio's and Duke Energy Indiana's Consolidated Statements of Cash Flows.
Collection fees received in connection with the servicing of transferred accounts receivable are included in Operation, maintenance and other on Duke Energy Ohio's and Duke Energy Indiana's Consolidated Statements of Operations and Comprehensive Income. The loss recognized on sales of receivables is calculated monthly by multiplying the 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.

Common_Stock

Common Stock	12 Months Ended
Common Stock	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Common Stock	'
	18. COMMON STOCK
	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. Duke Energy's participating securities are restricted stock units that are entitled to dividends declared on Duke Energy common shares during the restricted stock units' vesting period.
	On July 2, 2012, just prior to the close of the merger with Progress Energy, Duke Energy executed a one-for-three reverse stock split. All earnings per share amounts included in this 10-K are presented as if the one-for-three reverse stock split had been effective January 1, 2011. 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
	2013
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	2,640		706	$	3.74
	2012
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic	$	1,727		574	$	3.01
	Effect of dilutive securities:
	Stock options, performance and restricted stock				1
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — diluted	$	1,727		575	$	3.01
	2011
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	1,702		444	$	3.83

	As of December 31, 2013, 2012 and 2011, 2 million, 1 million and 3 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.
	For the years ended December 31, 2013, 2012 and 2011, Duke Energy declared dividends of $3.09 per share, $3.03 per share and $2.97 per share, respectively.

Severance

Severance	12 Months Ended
Severance	Dec. 31, 2013
Severance [Abstract]	'
Severance	'
	19. SEVERANCE
	2011 SEVERANCE PLAN
	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 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 have been 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 year ended December 31, 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 Consolidated Statements of Operations. The Duke Energy Registrants recorded insignificant amounts for severance expense during 2011 for past and ongoing severance plans.

			Years Ended December 31,
	(in millions)		2013			2012
	Duke Energy^(a)		$	34		$	201
	Duke Energy Carolinas			8			63
	Progress Energy			19			82
	Duke Energy Progress			14			55
	Duke Energy Florida			5			27
	Duke Energy Ohio			2			21
	Duke Energy Indiana			2			18

	(a)	Includes $5 million and $14 million of accelerated stock award expense and $2 million and $19 million of COBRA and healthcare reimbursement expenses for 2013 and 2012, respectively.

	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)			Balance at December 31, 2012			Provision / Adjustments		Cash Reductions		Balance at December 31, 2013
	Duke Energy			$	135		$	52	$	-123	$	64
	Duke Energy Carolinas				12			6		-13		5
	Progress Energy				43			49		-48		44
	Duke Energy Progress				23			8		-20		11
	Duke Energy Florida				6			31		-13		24

	As part of Duke Energy Carolinas' 2011 rate case, the NCUC approved the recovery of $101 million of previously recorded expenses related to a prior year Voluntary Opportunity Plan. This amount was recorded as a reduction to Operation, maintenance, and other within Operating Expenses on the Consolidated Statements of Operations and recognized as a Regulatory asset on the Consolidated Balance Sheets in 2012.

StockBased_Compensation

Stock-Based Compensation	12 Months Ended
Stock-Based Compensation	Dec. 31, 2013
Stock-Based Compensation [Abstract]	'
Stock-Based Compensation	'
	20. STOCK-BASED COMPENSATION
	Duke Energy's 2010 Long-Term Incentive Plan (the 2010 Plan) reserved 25 million shares of common stock for awards to employees and outside directors. Duke Energy has historically issued new shares upon exercising or vesting of share-based awards. However, Duke Energy may use a combination of new share issuances and open market repurchases for share-based awards that are exercised or become vested in the future. Duke Energy has not determined with certainty the amount of such new share issuances or open market repurchases.
	The 2010 Plan allows for a maximum of 6.25 million shares of common stock to be issued under various stock-based awards other than options and stock appreciation rights.
	In connection with the acquisition of Progress Energy in July 2012, Duke Energy assumed Progress Energy's 2007 Equity Incentive Plan (EIP). Stock-based awards granted under the Progress Energy EIP and held by Progress Energy employees were generally converted into outstanding Duke Energy stock-based compensation awards. The estimated fair value of these awards allocated to purchase price was $62 million. Refer to Note 2 for further information regarding the merger transaction.
	The following table summarizes the total expense recognized by each of the Duke Energy Registrants, net of tax, for stock-based compensation.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Duke Energy		$	52		$	48		$	32
	Duke Energy Carolinas			13			12			17
	Progress Energy			23			25			20
	Duke Energy Progress			14			16			12
	Duke Energy Florida			9			9			8
	Duke Energy Ohio			4			4			6
	Duke Energy Indiana			4			4			4

	Pretax stock-based compensation costs, the tax benefit associated with stock-based compensation expense, and stock-based compensation costs capitalized are included in the following table.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Stock options		$	2		$	2		$	2
	Restricted stock unit awards			49			43			27
	Performance awards			34			33			23
	Pretax stock-based compensation cost		$	85		$	78		$	52
	Tax benefit associated with stock-based compensation expense		$	33		$	30		$	20
	Stock-based compensation costs capitalized			3			2			2

	STOCK OPTIONS

	The following table summarizes information about stock options outstanding.

			Options (in thousands)			Weighted-Average Exercise Price			Weighted-Average Remaining Life		Aggregate Intrinsic Value (in millions)
	Outstanding at December 31, 2012			1,654		$	51
	Granted			310			69
	Exercised			-1,162			48
	Forfeited or expired			-9			41
	Outstanding at December 31, 2013			793			61			7y, 3m	$	6
	Exercisable at December 31, 2013			137			46			1y, 5m		3
	Options expected to vest			656			64			8y, 5m		3

	The exercise price of each option granted cannot be less than the market price of Duke Energy's common stock on the date of grant and the maximum option term is 10 years. The vesting periods range from immediate to three years. Options granted in 2013 and 2012 were expensed immediately; therefore, there is no future compensation cost associated with these options. The following table includes information related to Duke Energy's stock options.
			Years Ended December 31,
	(in millions)		2013			2012			2011
	Intrinsic value of options exercised		$	26		$	17		$	26
	Tax benefit related to options exercised			10			7			10
	Cash received from options exercised			9			21			74
	Stock options granted (in thousands)			310			340			358

	The following assumptions were used to determine the grant date fair value of stock options granted in 2013.

	Risk-free interest rate^(a)			1	%
	Expected dividend yield^(b)			4.7	%
	Expected life^(c)			6 years
	Expected volatility^(d)			18.1	%

	(a)	The risk-free rate is based upon the average of five-year and seven-year U.S. Treasury Constant Maturity rates as of the grant date.
	(b)	The expected dividend yield is based upon the most recent annualized dividend and the one-year average closing stock price.
	(c)	The expected life of options is derived from the simplified method approach.
	(d)	Volatility is based equally between historical and implied volatility. Historic volatility is based on Duke Energy's historical volatility over the expected life using daily stock prices. Implied volatility is the average for all option contracts with a term greater than six months using the strike price closest to the stock price on the valuation date.

	RESTRICTED STOCK UNIT AWARDS
	Restricted stock unit awards issued and outstanding generally vest over periods from immediate to three years. The following table includes information related to restricted stock unit awards.

		Years Ended December 31,
		2013			2012			2011
Shares awarded (in thousands)			612			443			636
Fair value (in millions)^(a)		$	42		$	28		$	34

(a)	Based on the market price of Duke Energy's common stock at the grant date.

The following table summarizes information about restricted stock unit awards outstanding.

			Shares (in thousands)			Weighted-Average Per Share Grant Date Fair Value
Outstanding at December 31, 2012				1,607		$	64
Granted				612			69
Vested				-794			63
Forfeited				-25			68
Outstanding at December 31, 2013				1,400			66
Restricted stock unit awards expected to vest				1,365			66

The total grant date fair value of shares vested during the years ended December 31, 2013, 2012 and 2011 was $50 million, $34 million and $19 million, respectively. At December 31, 2013, Duke Energy had $21 million of unrecognized compensation cost, which is expected to be recognized over a weighted-average period of 1 year and 9 months.
PERFORMANCE AWARDS
Stock-based awards issued and outstanding generally vest over three years if performance targets are met.
Certain performance awards granted in 2013, 2012 and 2011 contain market conditions based on the total shareholder return (TSR) of Duke Energy stock relative to a pre-defined peer group (relative TSR). These awards are valued using a path-dependent model that incorporates expected relative TSR into the fair value determination of Duke Energy's performance-based share awards. The model uses three-year historical volatilities and correlations for all companies in the pre-defined peer group, including Duke Energy, to simulate Duke Energy's relative TSR as of the end of the performance period. For each simulation, Duke Energy's relative TSR associated with the simulated stock price at the end of the performance period plus expected dividends within the period results in a value per share for the award portfolio. The average of these simulations is the expected portfolio value per share. Actual life to date results of Duke Energy's relative TSR for each grant is incorporated within the model.
Other performance awards not containing market conditions were awarded in 2012 and 2011. The performance goal for these awards is Duke Energy's return on equity over a three-year period. Awards are measured at grant date price.
The following table includes information related to performance awards.

		Years Ended December 31,
		2013			2012			2011
Shares awarded (in thousands)			633			352			432
Fair value (in millions)		$	28		$	19		$	20

The following table summarizes information about stock-based performance awards outstanding at the maximum level.

		Shares (in thousands)			Weighted-Average Per Share Grant Date Fair Value
Outstanding at December 31, 2012			2,346		$	47
Granted			633			45
Vested			-858			49
Forfeited			-299			46
Outstanding at December 31, 2013			1,822			46
Stock-based performance awards expected to vest			1,646			47

The total grant date fair value of shares vested during the years ended December 31, 2013, 2012 and 2011 was $42 million, $56 million and $33 million, respectively. At December 31, 2013, Duke Energy had $22 million of unrecognized compensation cost, which is expected to be recognized over a weighted-average period of 1 year and 11 months.

Employee_Benefit_Plans

Employee Benefit Plans	12 Months Ended
Employee Benefit Plans	Dec. 31, 2013
Employee Benefit Plans [Abstract]	'
Employee Benefit Plans	'
	21. EMPLOYEE BENEFIT PLANS
	DEFINED Benefit Retirement Plans
	Duke Energy maintains, and the Subsidiary Registrants participate in, qualified, non-contributory defined benefit retirement plans. The plans cover most U.S. employees using a cash balance formula. Under a cash balance formula, a plan participant accumulates a retirement benefit consisting of pay credits based upon a percentage of current eligible earnings based on age and/or years of service and interest credits. Certain employees are covered under plans that use a final average earnings formula. As of January 1, 2014, these defined benefit plans are closed to new participants. Under these average earnings formulas, a plan participant accumulates a retirement benefit equal to the sum of percentages of their (i) highest three-year or four-year average earnings, (ii) highest three-year or four-year average earnings in excess of covered compensation per year of participation (maximum of 35 years), and/or (iii) highest three or four-year average earnings times years of participation in excess of 35 years. Duke Energy also maintains, and the Subsidiary Registrants participate in, non-qualified, non-contributory defined benefit retirement plans which cover certain executives.
	Duke Energy uses a December 31 measurement date for its defined benefit retirement plan assets and obligations.
	Net periodic benefit costs disclosed in the tables below 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 the amounts of pension and other post-retirement benefit cost allocated by Duke Energy 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 affiliate that provide support to the Subsidiary Registrants. These allocated amounts are included in the governance and shared service costs discussed in Note 13.
	Duke Energy's policy is to fund amounts on an actuarial basis to provide assets sufficient to meet benefit payments to be paid to plan participants. The following table includes information related to the Duke Energy Registrants' contributions to its U.S. qualified defined benefit pension plans.

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Anticipated Contributions:
	2014		$	143		$	42		$	51		$	21		$	21		$	4		$	9
	Contributions Made:
	2013		$	250		$	—		$	250		$	63		$	133		$	—		$	—
	2012			304			—			346			141			128			—			—
	2011			200			33			334			217			112			48			52

	QUALIFIED PENSION PLANS

	Components of Net Periodic Pension Costs

			Year Ended December 31, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	167		$	49		$	60		$	22		$	30		$	6		$	11
	Interest cost on projected benefit obligation			320			80			116			50			53			21			28
	Expected return on plan assets			-549			-148			-199			-94			-87			-31			-46
	Amortization of actuarial loss			244			60			101			46			49			13			24
	Amortization of prior service (credit) cost			-11			-6			-4			-1			-2			―			1
	Other			7			2			2			1			1			―			1
	Net periodic pension costs^(a)(b)		$	178		$	37		$	76		$	24		$	44		$	9		$	19

			Year Ended December 31, 2012
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	122		$	35		$	63		$	25		$	30		$	6		$	9
	Interest cost on projected benefit obligation			307			90			127			58			56			31			30
	Expected return on plan assets			-472			-146			-188			-96			-81			-45			-46
	Amortization of actuarial loss			144			45			93			37			48			10			15
	Amortization of prior service cost (credit)			10			1			9			8			-1			1			1
	Other			6			2			2			1			1			―			―
	Net periodic pension costs^(a)(b)		$	117		$	27		$	106		$	33		$	53		$	3		$	9

			Year Ended December 31, 2011
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Service cost		$	96		$	37		$	51		$	20		$	24		$	7		$	11
	Interest cost on projected benefit obligation			232			85			132			61			57			32			30
	Expected return on plan assets			-384			-150			-182			-91			-78			-44			-45
	Amortization of actuarial loss			77			37			66			25			33			7			14
	Amortization of prior service cost			6			1			7			6			―			1			2
	Other			18			7			―			―			―			2			2
	Net periodic pension costs^(a)(b)		$	45		$	17		$	74		$	21		$	36		$	5		$	14

	(a)	Duke Energy amounts exclude $12 million, $14 million and $14 million for the years ended December 2013, 2012, and 2011, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy in April 2006.
	(b)	Duke Energy Ohio amounts exclude $6 million, $6 million and $7 million for the years ended December 2013, 2012, and 2011, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy in April 2006.

	Amounts Recognized in Accumulated Other Comprehensive Income and Regulatory Assets

			Year Ended December 31, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Regulatory assets, net decrease		$	-788		$	-205		$	-253		$	-109		$	-146		$	-96		$	-99
	Accumulated other comprehensive (income) loss
	Deferred income tax benefit		$	18		$	―		$	―		$	―		$	―		$	―		$	―
	Actuarial gains arising during the year			-33			―			-2			―			―			―			―
	Prior year service credit arising during the year			-1			―			―			―			―			―			―
	Amortization of prior year actuarial losses			-15			―			-3			―			―			―			―
	Reclassification of actuarial losses to regulatory assets			3			―			―			―			―			―			―
Net amount recognized in accumulated other comprehensive income		$	-28		$	―		$	-5		$	―		$	―		$	―		$	―

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net increase (decrease)		$	976		$	-111		$	-76		$	-89		$	23		$	22		$	17
Accumulated other comprehensive (income) loss
Deferred income tax benefit		$	14		$	―		$	―		$	―		$	―		$	15		$	―
Reclassification of actuarial losses to an affiliate			―			―			―			―			―			-48			―
Actuarial (gains) losses arising during the year			-2			―			3			―			―			―			―
Prior year service credit arising during the year			-7			―			―			―			―			―			―
Amortization of prior year actuarial losses			-13			―			-2			―			―			-3			―
Reclassification of actuarial losses to regulatory assets			-20			―			―			―			―			-1			―
Amortization of prior year service cost			-1			―			-1			―			―			-1			―
Net amount recognized in accumulated other comprehensive income		$	-29		$	―		$	―		$	―		$	―		$	-38		$	―

Reconciliation of Funded Status to Net Amount Recognized

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date		$	8,030		$	2,028		$	2,868		$	1,264		$	1,309		$	527		$	684
Service cost			167			49			60			22			30			6			11
Interest cost			320			80			116			50			53			21			28
Actuarial gains			-399			-73			-118			-26			-75			-71			-56
Transfers			―			-26			-7			-45			-17			-2			-2
Plan amendments			-41			-13			-19			-8			-7			―			―
Benefits paid			-567			-170			-161			-85			-60			-39			-33
Obligation at measurement date		$	7,510		$	1,875		$	2,739		$	1,172		$	1,233		$	442		$	632
Accumulated Benefit Obligation at measurement date		$	7,361		$	1,875		$	2,698		$	1,172		$	1,192		$	429		$	608
Change in Fair Value of Plan Assets
Plan assets at prior measurement date		$	7,754		$	2,151		$	2,647		$	1,289		$	1,150		$	446		$	627
Actual return on plan assets			705			207			215			108			93			43			62
Benefits paid			-567			-170			-161			-85			-60			-39			-33
Transfers			―			-26			-7			-45			-17			-2			-2
Employer contributions			250			―			250			63			133			―			―
Plan assets at measurement date		$	8,142		$	2,162		$	2,944		$	1,330		$	1,299		$	448		$	654
Funded status of plan		$	632		$	287		$	205		$	158		$	66		$	6		$	22

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date		$	4,880		$	1,831		$	2,729		$	1,263		$	1,179		$	627		$	613
Obligation assumed from acquisition			2,850			―			―			―			―			―			―
Service cost			122			35			63			25			30			6			9
Interest cost			307			90			127			58			56			31			30
Actuarial losses			489			73			166			34			120			68			76
Transfers			―			176			―			―			―			-167			―
Plan amendments			-170			-52			-64			-43			-10			―			-1
Benefits paid			-448			-125			-153			-73			-66			-38			-43
Obligation at measurement date		$	8,030		$	2,028		$	2,868		$	1,264		$	1,309		$	527		$	684
Accumulated Benefit Obligation at measurement date		$	7,843		$	2,028		$	2,820		$	1,264		$	1,261		$	501		$	653
Change in Fair Value of Plan Assets
Plan assets at prior measurement date		$	4,741		$	1,820		$	2,191		$	1,091		$	969		$	565		$	582
Assets received from acquisition			2,285			―			―			―			―			―			―
Actual return on plan assets			872			280			263			130			119			86			88
Benefits paid			-448			-125			-153			-73			-66			-38			-43
Transfers			―			176			―			―			―			-167			―
Employer contributions			304			―			346			141			128			―			―
Plan assets at measurement date		$	7,754		$	2,151		$	2,647		$	1,289		$	1,150		$	446		$	627
Funded status of plan		$	-276		$	123		$	-221		$	25		$	-159		$	-81		$	-57

Amounts Recognized in the Consolidated Balance Sheets

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Prefunded pension^(a)		$	632		$	287		$	230		$	158		$	66		$	2		$	75
Noncurrent pension liability		$	―		$	―		$	25		$	―		$	―		$	-4		$	53
Net asset recognized		$	632		$	287		$	205		$	158		$	66		$	6		$	22
Regulatory assets		$	1,599		$	377		$	826		$	363		$	395		$	48		$	147
Accumulated other comprehensive (income) loss
Deferred income tax asset		$	-41		$	―		$	-9		$	―		$	―		$	―		$	―
Prior service credit			-5			―			―			―			―			―			―
Net actuarial loss			121			―			21			―			―			―			―
Net amounts recognized in accumulated other comprehensive loss^(b)		$	75		$	―		$	12		$	―		$	―		$	―		$	―
Amounts to be recognized in net periodic pension expense in the next year
Unrecognized net actuarial loss		$	149		$	35		$	71		$	33		$	32		$	4		$	7
Unrecognized prior service credit			-15			-8			-4			-2			-1			―			―

		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Prefunded pension^(a)		$	163		$	123		$	―		$	25		$	―		$	―		$	―
Noncurrent pension liability		$	439		$	―		$	221		$	―		$	159		$	81		$	57
Net asset (liability) recognized		$	-276		$	123		$	-221		$	25		$	-159		$	-81		$	-57
Regulatory assets		$	2,387		$	582		$	1,079		$	472		$	541		$	144		$	246
Accumulated other comprehensive (income) loss
Deferred income tax asset		$	-59		$	―		$	-9		$	―		$	―		$	―		$	―
Prior service credit			-4			―			―			―			―			―			―
Net actuarial loss			166			―			26			―			―			―			―
Net amounts recognized in accumulated other comprehensive loss^(b)		$	103		$	―		$	17		$	―		$	―		$	―		$	―

(a)	Included in Other within Investments and Other Assets on the Consolidated Balance Sheets.
(b)	Excludes accumulated other comprehensive income of $16 million and $9 million as of 2013 and 2012, respectively, net of tax, associated with a Brazilian retirement plan.

Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets

As of December 31, 2013, no qualified pension plans had an accumulated benefit obligation in excess of plan assets.

		31-Dec-12
(in millions)		Duke Energy			Progress Energy			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Projected benefit obligation		$	5,396		$	2,868		$	1,309		$	527		$	684
Accumulated benefit obligation			5,201			2,820			1,261			501			653
Fair value of plan assets			4,957			2,647			1,150			446			627

Assumptions Used for Pension Benefits Accounting
The discount rate used to determine the current year pension obligation and following year's pension expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan's projected benefit payments discounted at this rate with the market value of the bonds selected.
The average remaining service period of active covered employees is nine years for Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana and eight years for Progress Energy, Duke Energy Progress and Duke Energy Florida.
The following tables present the assumptions used for pension benefit accounting. For Progress Energy plans, the assumptions used in 2012 to determine net periodic pension cost reflect remeasurement as of July 1, 2012, due to the merger between Duke Energy and Progress Energy.

		Duke Energy									Progress Energy
		December 31,									December 31,
		2013			2012			2011			2013			2012			2011
Benefit Obligations
Discount rate		4.7	%		4.1	%		5.1	%		4.7	%		4.1	%		4.75	%
Salary increase		4.4	%		4.3	%		4.4	%		4	%		4	%		4	%
Net Periodic Benefit Cost
Discount rate		4.1	%		4.60-5.10	%		5	%		4.1	%		4.60-4.75	%		5.55	%
Salary increase		4.3	%		4.4	%		4.1	%		4	%		4	%		4.5	%
Expected long-term rate of return on plan assets		7.75	%		8	%		8.25	%		7.75	%		8.00-8.25	%		8.5	%

Expected Benefit Payments

(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Years ending December 31,
2014		$	667		$	224		$	190		$	98		$	68		$	36		$	47
2015			643			218			185			92			71			35			45
2016			640			212			190			93			74			34			46
2017			633			205			191			91			77			34			44
2018			623			196			194			91			80			34			46
2019 - 2023			2,933			807			969			422			430			171			227

NON-QUALIFIED PENSION PLANS

Components of Net Periodic Pension Costs

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	3		$	―		$	1		$	1		$	―		$	―		$	―
Interest cost on projected benefit obligation			13			1			7			1			1			―			―
Amortization of actuarial loss			5			―			3			1			1			―			―
Amortization of prior service credit			-1			―			-1			―			―			―			―
Net periodic pension costs		$	20		$	1		$	10		$	3		$	2		$	―		$	―

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	2		$	―		$	2		$	1		$	―		$	―		$	―
Interest cost on projected benefit obligation			12			1			8			1			2			―			―
Amortization of actuarial loss			4			―			5			1			―			―			―
Amortization of prior service cost (credit)			1			―			-1			―			―			―			―
Net periodic pension costs		$	19		$	1		$	14		$	3		$	2		$	―		$	―

		Year Ended December 31, 2011
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	1		$	―		$	2		$	1		$	―		$	―		$	―
Interest cost on projected benefit obligation			8			1			9			2			2			―			―
Amortization of actuarial loss			―			―			3			―			1			―			―
Amortization of prior service cost			2			―			―			―			―			―			―
Net periodic pension costs		$	11		$	1		$	14		$	3		$	3		$	―		$	―

Amounts Recognized in Accumulated Other Comprehensive Income and Regulatory Assets and Liabilities

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net (decrease) increase		$	-14		$	1		$	-16		$	-4		$	-3		$	―		$	-2
Regulatory liabilities, net increase		$	5		$	―		$	―		$	―		$	―		$	―		$	―
Accumulated other comprehensive (income) loss
Deferred income tax benefit		$	―		$	―		$	1		$	―		$	―		$	―		$	―
Actuarial losses (gains) arising during the year			2			―			-5			―			―			―			―
Prior year service credit arising during the year			-1			―			―			―			―			―			―
Net amount recognized in accumulated other comprehensive loss (income)		$	1		$	―		$	-4		$	―		$	―		$	―		$	―

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net increase (decrease)		$	34		$	―		$	-6		$	-2		$	1		$	―		$	―
Regulatory liabilities, net increase		$	-8		$	―		$	―		$	―		$	―		$	―		$	―
Accumulated other comprehensive (income) loss
Deferred income tax benefit		$	―		$	―		$	-1		$	―		$	―		$	―		$	―
Actuarial (gains) losses arising during the year			-2			―			3			―			―			―			―
Net amount recognized in accumulated other comprehensive (income) loss		$	-2		$	―		$	2		$	―		$	―		$	―		$	―

Reconciliation of Funded Status to Net Amount Recognized

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date		$	335		$	16		$	176		$	38		$	45		$	4		$	5
Service cost			3			―			1			1			―			―			―
Interest cost			13			1			7			1			1			―			―
Actuarial losses			-15			1			-11			-3			-3			-1			―
Settlements			-5			―			―			―			―			―			―
Plan amendments			-1			―			―			―			―			―			―
Transfers			―			―			-21			―			―			―			―
Benefits paid			-26			-3			-12			-3			-4			―			―
Obligation at measurement date		$	304		$	15		$	140		$	34		$	39		$	3		$	5
Accumulated Benefit Obligation at measurement date		$	302		$	15		$	140		$	34		$	39		$	3		$	5
Change in Fair Value of Plan Assets
Plan assets at prior measurement date		$	―		$	―		$	―		$	―		$	―		$	―		$	―
Benefits paid			-26			-3			-12			-3			-4			―			―
Employer contributions			26			3			12			3			4			―			―
Plan assets at measurement date		$	―		$	―		$	―		$	―		$	―		$	―		$	―

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Obligation at prior measurement date		$	160		$	18		$	177		$	39		$	44		$	4		$	5
Obligation assumed from acquisition			172			―			―			―			―			―			―
Service cost			2			―			2			1			―			―			―
Interest cost			12			1			8			1			2			―			―
Actuarial losses			18			―			11			3			3			―			―
Plan amendments			-5			―			-12			-4			-2			―			―
Transfers			―			1			―			―			―			―			―
Benefits paid			-24			-4			-10			-2			-2			―			―
Obligation at measurement date		$	335		$	16		$	176		$	38		$	45		$	4		$	5
Accumulated Benefit Obligation at measurement date		$	332		$	16		$	175		$	36		$	44		$	4		$	5
Change in Fair Value of Plan Assets
Plan assets at prior measurement date		$	―		$	―		$	―		$	―		$	―		$	―		$	―
Benefits paid			-24			-4			-10			-2			-3			―			―
Employer contributions			24			4			10			2			3			―			―
Plan assets at measurement date		$	―		$	―		$	―		$	―		$	―		$	―		$	―

Amounts Recognized in the Consolidated Balance Sheets

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current pension liability^(a)		$	30		$	2		$	11		$	2		$	3		$	―		$	―
Noncurrent pension liability			274			13			129			32			36			3			5
Total accrued pension liability		$	304		$	15		$	140		$	34		$	39		$	3		$	5
Regulatory assets		$	45		$	4		$	18		$	3		$	6		$	―		$	―
Regulatory liabilities		$	7		$	―		$	―		$	―		$	―		$	―		$	―
Accumulated other comprehensive (income) loss
Deferred income tax asset		$	―		$	―		$	-3		$	―		$	―		$	―		$	―
Prior service credit			-1			―			―			―			―			―			―
Net actuarial loss			1			―			7			―			―			―			―
Net amounts recognized in accumulated other comprehensive loss		$	―		$	―		$	4		$	―		$	―		$	―		$	―
Amounts to be recognized in net periodic pension expense in the next year
Unrecognized net actuarial loss		$	5		$	―		$	2		$	1		$	―		$	―		$	―
Unrecognized prior service credit			-1			―			-1			-1			―			―			―

		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current pension liability^(a)		$	30		$	3		$	11		$	2		$	3		$	―		$	―
Noncurrent pension liability			305			13			165			36			42			4			5
Total accrued pension liability		$	335		$	16		$	176		$	38		$	45		$	4		$	5
Regulatory assets		$	59		$	3		$	34		$	7		$	9		$	―		$	2
Regulatory liabilities		$	2		$	―		$	―		$	―		$	―		$	―		$	―
Accumulated other comprehensive (income) loss
Deferred income tax asset		$	―		$	―		$	-4		$	―		$	―		$	―		$	―
Net actuarial (gain) loss			-1			―			12			―			―			―			―
Net amounts recognized in accumulated other comprehensive (income) loss		$	-1		$	―		$	8		$	―		$	―		$	―		$	―

(a)	Included in Other within Current Liabilities on the Consolidated Balance Sheets.

Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Projected benefit obligation		$	304		$	15		$	140		$	34		$	39		$	3		$	5
Accumulated benefit obligation			302			15			140			34			39			3			5

		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Projected benefit obligation		$	335		$	16		$	176		$	38		$	45		$	4		$	5
Accumulated benefit obligation			332			16			175			36			44			4			5

Assumptions Used for Pension Benefits Accounting
The discount rate used to determine the current year pension obligation and following year's pension expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plan's projected benefit payments discounted at this rate with the market value of the bonds selected.
The average remaining service period of active covered employees is 13 years for Duke Energy and Progress Energy, nine years for Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, 12 years for Duke Energy Progress and 17 years for Duke Energy Florida.
The following tables present the assumptions used for pension benefit accounting. For Progress Energy plans, the assumptions used in 2012 to determine net periodic pension cost reflect remeasurement as of July 1, 2012, due to the merger between Duke Energy and Progress Energy.

		Duke Energy									Progress Energy
		December 31,									December 31,
		2013			2012			2011			2013			2012			2011
Benefit Obligations
Discount rate		4.7	%		4.1	%		5.1	%		4.7	%		4.1	%		4.8	%
Salary increase		4.4	%		4.3	%		4.4	%		―	%		―	%		5.25	%
Net Periodic Benefit Cost
Discount rate		4.1	%		4.60-5.10	%		5	%		4.1	%		4.60-4.80	%		5.6	%
Salary increase		4.3	%		4.4	%		4.1	%		―	%		―	%		5.25	%

Expected Benefit Payments

(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Years ending December 31,
2014		$	31		$	3		$	11		$	2		$	3		$	―		$	―
2015			28			2			11			2			3			―			―
2016			26			2			11			2			3			―			―
2017			27			2			11			2			3			―			―
2018			24			2			11			2			3			―			―
2019 - 2023			112			6			52			13			15			1			2

Other Post-Retirement Benefit Plans
Duke Energy provides, and the Subsidiary Registrants participate in, some health care and life insurance benefits for retired employees on a contributory and non-contributory basis. 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, dental, and prescription drug coverage and are subject to certain limitations, such as deductibles and co-payments.
Duke Energy did not make any pre-funding contributions to its other post-retirement benefit plans during the years ended December 31, 2013, 2012 or 2011.
Components of Net Periodic Other Post-Retirement Benefit Costs

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	24		$	2		$	18		$	9		$	7		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation			68			13			41			22			16			2			5
Expected return on plan assets			-14			-11			―			―			―			-1			-1
Amortization of actuarial loss (gain)			52			3			57			34			16			-1			1
Amortization of prior service credit			-41			-7			-30			-20			-6			-1			―
Net periodic post-retirement benefit costs^(a)(b)		$	89		$	―		$	86		$	45		$	33		$	―		$	6

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	16		$	2		$	17		$	8		$	7		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation			56			15			43			23			18			3			6
Expected return on plan assets			-17			-10			-2			―			-2			-1			-1
Amortization of actuarial loss (gain)			14			3			35			20			12			-2			―
Amortization of prior service credit			-8			-5			―			―			―			-1			―
Amortization of net transition liability			10			7			4			―			3			―			―
Special termination benefit cost			9			1			5			2			1			―			―
Net periodic post-retirement benefit costs^(a)(b)		$	80		$	13		$	102		$	53		$	39		$	―		$	6

		Year Ended December 31, 2011
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost		$	7		$	2		$	11		$	5		$	5		$	1		$	1
Interest cost on accumulated post-retirement benefit obligation			35			16			41			20			18			3			7
Expected return on plan assets			-15			-10			-2			―			-2			-1			-1
Amortization of actuarial (gain) loss			-3			2			12			5			7			-2			2
Amortization of prior service credit			-8			-5			―			―			―			-1			―
Amortization of net transition liability			10			9			5			1			4			―			―
Net periodic post-retirement benefit costs^(a)(b)		$	26		$	14		$	67		$	31		$	32		$	―		$	9

(a)	Duke Energy amounts exclude $8 million, $9 million and $8 million for the years ended December 31, 2013, 2012 and 2011, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy in April 2006.
(b)	Duke Energy Ohio amounts exclude $2 million for each of the years ended December 31, 2013, 2012 and 2011, respectively, of regulatory asset amortization resulting from purchase accounting adjustments associated with Duke Energy’s merger with Cinergy in April 2006.

Amounts Recognized in Accumulated Other Comprehensive Income and Regulatory Assets and Liabilities

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net (decrease) increase		$	-683		$	-51		$	-634		$	-388		$	-166		$	―		$	-6
Regulatory liabilities, net increase (decrease)		$	30		$	―		$	―		$	―		$	―		$	3		$	9
Accumulated other comprehensive (income) loss
Deferred income tax benefit		$	2		$	―		$	―		$	―		$	―		$	―		$	―
Actuarial gains arising during the year			-4			―			―			―			―			―			―
Prior year service credit arising during the year			-3			―			―			―			―			―			―
Amortization of prior year actuarial loss			1			―			―			―			―			―			―
Net amount recognized in accumulated other comprehensive income		$	-4		$	―		$	―		$	―		$	―		$	―		$	―

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Regulatory assets, net increase (decrease)		$	484		$	-20		$	228		$	170		$	28		$	―		$	-6
Regulatory liabilities, net decrease		$	-6		$	―		$	―		$	―		$	―		$	-1		$	-2
Accumulated other comprehensive (income) loss
Deferred income tax expense		$	-2		$	―		$	―		$	―		$	―		$	-4		$	―
Reclassification of actuarial losses to an affiliate			―			―			―			―			―			6			―
Actuarial losses arising during the year			―			―			―			―			―			2			―
Prior year service cost arising during the year			―			―			―			―			―			1			―
Amortization of prior year actuarial loss			―			―			―			―			―			1			―
Reclassification of actuarial gains to regulatory liabilities			4			―			―			―			―			―			―
Net amount recognized in accumulated other comprehensive loss		$	2		$	―		$	―		$	―		$	―		$	6		$	―

Reconciliation of Funded Status to Accrued Other Post-Retirement Benefit Costs

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Accumulated post-retirement benefit obligation at prior measurement date		$	1,794		$	316		$	1,128		$	612		$	413		$	48		$	136
Service cost			24			2			18			9			7			1			1
Interest cost			68			13			41			22			16			2			5
Plan participants' contributions			47			15			14			6			7			3			3
Actuarial gains			-227			-32			-156			-73			-70			-6			-12
Transfers			―			―			-1			-8			―			―			―
Benefits paid			-132			-36			-60			-26			-31			-6			-14
Plan amendments			-476			-16			-455			-311			-91			―			-3
Accrued retiree drug subsidy			8			3			4			2			2			―			2
Accumulated post-retirement benefit obligation at measurement date		$	1,106		$	265		$	533		$	233		$	253		$	42		$	118
Change in Fair Value of Plan Assets
Plan assets at prior measurement date		$	198		$	134		$	―		$	―		$	―		$	7		$	17
Actual return on plan assets			18			13			―			―			―			2			2
Benefits paid			-132			-36			-60			-26			-31			-6			-14
Transfers^(a)			―			-1			―			―			―			―			―
Employer contributions			83			18			46			20			24			2			10
Plan participants' contributions			47			15			14			6			7			3			3
Plan assets at measurement date		$	214		$	143		$	―		$	―		$	―		$	8		$	18

		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Change in Projected Benefit Obligation
Accumulated post-retirement benefit obligation at prior measurement date		$	667		$	312		$	841		$	407		$	368		$	61		$	135
Obligation assumed from acquisition			977			―			―			―			―			―			―
Service cost			16			2			17			8			7			1			1
Interest cost			56			15			43			23			18			3			6
Plan participants' contributions			41			18			13			5			7			4			8
Actuarial gains			198			28			291			205			49			3			-2
Transfers			―			9			―			―			―			-16			―
Benefits paid			-105			-38			-61			-24			-33			-8			-13
Special termination benefit cost			9			1			5			2			1			―			―
Plan amendments			-70			-33			-25			-16			-6			―			―
Accrued retiree drug subsidy			5			2			4			2			2			―			1
Accumulated post-retirement benefit obligation at measurement date		$	1,794		$	316		$	1,128		$	612		$	413		$	48		$	136
Change in Fair Value of Plan Assets
Plan assets at prior measurement date		$	181		$	120		$	37		$	―		$	37		$	9		$	14
Actual return on plan assets			23			12			2			―			2			1			2
Benefits paid			-105			-38			-61			-24			-33			-8			-13
Transfers^(a)			―			5			-39			―			-39			-3			―
Employer contributions			58			17			48			19			26			4			6
Plan participants' contributions			41			18			13			5			7			4			8
Plan assets at measurement date		$	198		$	134		$	―		$	―		$	―		$	7		$	17

(a)	Progress Energy and Duke Energy Florida amounts reflect assets that did not meet the definition of plan assets. These assets are included in Other within Investments and Other Assets on the Consolidated Balance Sheets.

Amounts Recognized in the Consolidated Balance Sheets

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current post-retirement liability^(a)		$	39		$	―		$	36		$	17		$	16		$	2		$	―
Noncurrent post-retirement liability			853			122			497			216			237			32			100
Total accrued post-retirement liability		$	892		$	122		$	533		$	233		$	253		$	34		$	100
Regulatory assets		$	-162		$	-34		$	-129		$	-97		$	4		$	―		$	71
Regulatory liabilities		$	131		$	―		$	―		$	―		$	―		$	21		$	77
Accumulated other comprehensive (income) loss
Deferred income tax liability		$	4		$	―		$	―		$	―		$	―		$	―		$	―
Prior service credit			-5			―			―			―			―			―			―
Net actuarial gain			-6			―			―			―			―			―			―
Net amounts recognized in accumulated other comprehensive income		$	-7		$	―		$	―		$	―		$	―		$	―		$	―
Amounts to be recognized in net periodic pension expense in the next year
Unrecognized net actuarial loss (gain)		$	38		$	3		$	46			30		$	10		$	-2		$	-6
Unrecognized prior service credit			-125			-10			-112			-73			-21			―			―

		31-Dec-12
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current post-retirement liability^(a)		$	50		$	―		$	47		$	23		$	20		$	2		$	―
Noncurrent post-retirement liability			1,546			182			1,081			589			393			39			119
Total accrued post-retirement liability		$	1,596		$	182		$	1,128		$	612		$	413		$	41		$	119
Regulatory assets		$	521		$	17		$	505		$	291		$	170		$	―		$	77
Regulatory liabilities		$	101		$	―		$	―		$	―		$	―		$	18		$	68
Accumulated other comprehensive (income) loss
Deferred income tax liability		$	2		$	―		$	―		$	―		$	―		$	―		$	―
Prior service credit			-3			―			―			―			―			―			―
Net actuarial gain			-2			―			―			―			―			―			―
Net amounts recognized in accumulated other comprehensive income		$	-3		$	―		$	―		$	―		$	―		$	―		$	―

(a)	Included in Other within Current Liabilities on the Consolidated Balance Sheets.

Assumptions Used for Other Post-Retirement Benefits Accounting
The discount rate used to determine the current year other post-retirement benefits obligation and following year's other post-retirement benefits expense is based on a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flow to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of non-callable corporate bonds rated Aa quality or higher. After the bond portfolio is selected, a single interest rate is determined that equates present value of the plan's projected benefit payments discounted at this rate with the market value of the bonds selected.
The following tables present the assumptions used for other post-retirement benefits accounting. For Progress Energy plans, the assumptions used in 2012 to determine net periodic other post-retirement benefit cost reflect remeasurement as of July 1, 2012, due to the merger between Duke Energy and Progress Energy.

		Duke Energy									Progress Energy
		December 31,									December 31,
		2013			2012			2011			2013			2012			2011
Benefit Obligations
Discount rate		4.7	%		4.1	%		5.1	%		4.7	%		4.1	%		4.85	%
Net Periodic Benefit Cost
Discount rate		4.1	%		4.60-5.10	%		5	%		4.1	%		4.60-4.85	%		5.7	%
Expected long-term rate of return on plan assets		7.75	%		5.20-8.00	%		5.36-8.25	%		―	%		N/A-5.00	%		5	%
Assumed tax rate		35	%		35	%		35	%

Assumed Health Care Cost Trend Rate

		December 31,
		2013			2012
Health care cost trend rate assumed for next year		8.5	%		8.5	%
Rate to which the cost trend is assumed to decline (the ultimate trend rate)		5	%		5	%
Year that rate reaches ultimate trend		2021			2020

Sensitivity to Changes in Assumed Health Care Cost Trend Rates

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
1-Percentage Point Increase
Effect on total service and interest costs		$	11		$	2		$	7		$	4		$	3		$	1		$	1
Effect on post-retirement benefit obligation			42			10			20			9			10			2			4
1-Percentage Point Decrease
Effect on total service and interest costs			-9			-1			-6			-3			-2			—			-1
Effect on post-retirement benefit obligation			-36			-9			-16			-7			-8			-1			-4

Expected Benefit Payments

(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Years ending December 31,
	2014	$	85		$	21		$	36		$	17		$	17		$	4		$	11
	2015		88			22			38			17			17			4			12
	2016		89			23			38			18			17			4			12
	2017		89			23			38			18			17			3			11
	2018		89			24			38			18			17			3			11
	2019 - 2023		413			109			180			81			84			17			47

Plan Assets
Description and Allocations
Duke Energy Master Retirement Trust
Assets for both the qualified pension and other post-retirement benefits are maintained in the Duke Energy Master Retirement Trust. Approximately 98 percent of the Duke Energy Master Retirement Trust assets were allocated to qualified pension plans and approximately 2 percent were allocated to other post-retirement plans, as of December 31, 2013 and 2012. The investment objective of the Duke Energy Master Retirement Trust is to achieve reasonable returns, subject to a prudent level of portfolio risk, for the purpose of enhancing the security of benefits for plan participants.
The asset allocation targets were set after considering the investment objective and the risk profile. Equity securities are held for their high expected return. Debt securities, hedge funds, real estate and other global securities are held for diversification. Investments within asset classes are to be diversified to achieve broad market participation and reduce the impact of individual managers or investments. Duke Energy regularly reviews its actual asset allocation and periodically rebalances its investments to the targeted allocation when considered appropriate.
Qualified pension and other post-retirement benefits for the Subsidiary Registrants are derived from the Duke Energy Master Retirement Trust, as such, each are allocated their proportionate share of the assets discussed below.
The following table includes the target asset allocations by asset class at December 31, 2013 and the actual asset allocations for the Duke Energy Master Retirement Trust.

						Actual Allocation at December 31,
		Target Allocation				2013			2012
U.S. equity securities			10	%		10	%		28	%
Non-U.S. equity securities			8	%		8	%		15	%
Global equity securities			10	%		10	%		10	%
Global private equity securities			3	%		3	%		3	%
Debt securities			63	%		63	%		32	%
Hedge funds			2	%		3	%		4	%
Real estate and cash			2	%		1	%		4	%
Other global securities			2	%		2	%		4	%
Total			100	%		100	%		100	%

Progress Energy Master Retirement Trust
As of December 31, 2012, assets for Progress Energy qualified pension benefits were maintained in the Progress Energy Master Retirement Trust. As of January 1, 2013, assets previously held in the Progress Energy Master Retirement Trust were transferred into the Duke Energy Master Retirement Trust. The following table includes the actual asset allocations for the Progress Energy Master Retirement Trust at December 31, 2012.

			Actual Allocation at December 31,
			2012
U.S. equity securities			20	%
Non-U.S. equity securities			14	%
Global equity securities			8	%
Global private equity securities			10	%
Debt securities			35	%
Hedge funds			9	%
Real estate and cash			1	%
Other global securities			3	%
Total			100	%

VEBA I
Duke Energy also invests other post-retirement assets in the Duke Energy Corporation Employee Benefits Trust (VEBA I). The investment objective of VEBA I is to achieve sufficient returns, subject to a prudent level of portfolio risk, for the purpose of promoting the security of plan benefits for participants. VEBA I is passively managed.
The following table includes the weighted-average returns expected by asset classes and the target asset allocations at December 31, 2013 and the actual asset allocations for VEBA I.

						Actual Allocation at December 31,
		Target Allocation				2013			2012
U.S. equity securities			30	%		29	%		23	%
Debt securities			45	%		29	%		32	%
Cash			25	%		42	%		45	%
Total			100	%		100	%		100	%

Fair Value Measurements
Duke Energy classifies recurring and non-recurring fair value measurements based on the fair value hierarchy as discussed in Note 16.
Valuation methods of the primary fair value measurements disclosed above are as follows:
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 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.
Investments in short-term investment funds
Investments in short-term investment funds are valued at the net asset value of units held at year end. Investments in short-term investment funds with published prices are valued as Level 1. Investments in short-term investment funds with unpublished prices are valued as Level 2.
Investments in real estate investment trusts
Investments in real estate investment trusts are valued based upon property appraisal reports prepared by independent real estate appraisers. The Chief Real Estate Appraiser of the asset manager is responsible for assuring that the valuation process provides independent and reasonable property market value estimates. An external appraisal management firm not affiliated with the asset manager has been appointed to assist the Chief Real Estate Appraiser in maintaining and monitoring the independence and the accuracy of the appraisal process.
Duke Energy Master Retirement Trust

The following tables provide the fair value measurement amounts for the Duke Energy Master Retirement Trust qualified pension and other post-retirement assets.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Equity securities		$	2,877		$	1,801		$	1,022		$	54
Corporate debt securities			2,604			―			2,601			3
Short-term investment funds			1,158			254			904			―
Partnership interests			307			―			―			307
Hedge funds			164			―			111			53
Real estate trusts			95			―			―			95
U.S. government securities			927			―			927			―
Guaranteed investment contracts			33			―			―			33
Governments bonds - foreign			19			―			18			1
Cash			58			58			―			―
Government and commercial mortgage backed securities			7			―			7			―
Net pending transactions and other investments			12			7			5			―
Total assets^(a)		$	8,261		$	2,120		$	5,595		$	546

(a)	Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana were allocated approximately 28 percent, 35 percent, 16 percent, 16 percent, 5 percent and 8 percent, respectively, of the Duke Energy Master Retirement Trust assets at December 31, 2013. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to the Subsidiary Registrants using these percentages.

		31-Dec-12
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Equity securities		$	2,993		$	1,415		$	1,575		$	3
Corporate debt securities			1,391			―			1,388			3
Short-term investment funds			100			23			77			―
Partnership interests			141			―			―			141
Hedge funds			97			―			97			―
Real estate trusts			167			―			―			167
U.S. government securities			237			―			237			―
Guarantees investment contracts			37			―			―			37
Governments bonds - foreign			65			―			64			1
Cash			4			4			―			―
Asset backed securities			14			―			14			―
Net pending transactions and other investments			-16			-21			5			―
Total assets^(a)		$	5,230		$	1,421		$	3,457		$	352

(a)	Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana were allocated approximately 43 percent, 9 percent and 12 percent, respectively, of the Duke Energy Master Retirement Trust assets at December 31, 2012. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana using these percentages.

The following tables provide a reconciliation of beginning and ending balances of assets of master trusts measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3).

(in millions)		2013			2012
Balance at January 1		$	352		$	322
Combination of trust assets			288			―
Purchases, sales, issuances and settlements
Purchases			25			21
Sales			-152			-4
Total gains (losses) and other			33			13
Balance at December 31		$	546		$	352

Progress Energy Master Retirement Trust

The following table provides the fair value measurement amounts for the Progress Energy Master Retirement Trust qualified pension assets.

		31-Dec-12
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Equity securities		$	1,094		$	361		$	733		$	―
Corporate debt securities			432			―			432			―
Partnership interests			154			―			―			154
Hedge funds			313			―			189			124
U.S. government securities			515			405			110			―
Governments bonds - foreign			6			―			6			―
Cash			160			113			47			―
Net pending transactions and other investments			16			―			6			10
Total assets^(a)		$	2,690		$	879		$	1,523		$	288

(a)	Duke Energy Progress and Duke Energy Florida were allocated approximately 48 percent and 44 percent, respectively, of the Progress Energy Master Trust assets at December 31, 2012. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to Duke Energy Progress and Duke Energy Florida using these percentages.

The following tables provide a reconciliation of beginning and ending balances of Progress Trust assets measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3).

(in millions)		2013			2012
Balance at January 1		$	288		$	311
Combination of trust assets			-288			―
Purchases, sales, issuances and settlements
Purchases			―			13
Sales			―			-14
Transfers in and/or out of level 3			―			-41
Total gains (losses) and other			―			19
Balance at December 31		$	―		$	288

VEBA I

The following tables provide the fair value measurement amounts for VEBA I other post-retirement assets.

		31-Dec-13
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Cash and cash equivalents		$	21		$	―		$	21		$	―
Equity securities			15			―			15			―
Debt securities			15			―			15			―
Total assets		$	51		$	―		$	51		$	―

		31-Dec-12
(in millions)		Total Fair Value			Level 1			Level 2			Level 3
Cash and cash equivalents		$	22		$	―		$	22		$	―
Equity securities			12			―			12			―
Debt securities			16			―			16			―
Total assets		$	50		$	―		$	50		$	―

Employee Savings Plans
Duke Energy sponsors, and the Subsidiary Registrants participate in, employee savings plans that cover substantially all U.S. employees. 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 earnings per share.
The following table includes pretax employer matching contributions made by Duke Energy and expensed by the Subsidiary Registrants.
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Years ended December 31,
	2013	$	134		$	45		$	45		$	25		$	14		$	3		$	7
	2012		107			37			45			24			15			4			6
	2011		86			37			44			23			14			4			8

Income_Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2013
Income Taxes And Other Taxes [Abstract]	'
Income Taxes	'
	22. INCOME TAXES
	Income Tax Expense
	Components of Income Tax Expense

			Year Ended December 31, 2013
	(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Current income taxes
	Federal		$	-123		$	49		$	-221		$	-70		$	-143		$	-21		$	-88
	State			-37			11			-37			-10			-13			-2			7
	Foreign			151			―			―			―			―			―			―
	Total current income taxes			-9			60			-258			-80			-156			-23			-81
	Deferred income taxes
	Federal			1,129			464			555			316			326			93			276
	State			142			75			84			59			44			5			29
	Foreign			14			―			―			―			―			―			―
	Total deferred income taxes^(a)			1,285			539			639			375			370			98			305
	Investment tax credit amortization			-15			-5			-8			-7			-1			―			-1
	Income tax expense from continuing operations			1,261			594			373			288			213			75			223
	Tax benefit from discontinued operations			-27			―			-26			―			―			―			―
	Total income tax expense included in Consolidated Statements of Operations		$	1,234		$	594		$	347		$	288		$	213		$	75		$	223

	(a)	Includes benefits of net operating loss (NOL) carryforwards of $837 million at Duke Energy, $458 million at Progress Energy, $64 million at Duke Energy Progress, $301 million at Duke Energy Florida, $29 million at Duke Energy Ohio and $179 million at Duke Energy Indiana.


			Year Ended December 31, 2012
	(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Current income taxes
	Federal		$	-46		$	-1		$	-88		$	-48		$	6		$	26		$	-27
	State			35			-25			2			-6			―			11			27
	Foreign			133			―			―			―			―			―			―
	Total current income taxes			122			-26			-86			-54			6			37			―
	Deferred income taxes
	Federal			513			408			226			162			121			72			-47
	State			64			77			40			9			21			-9			-25
	Foreign			20			―			―			―			―			―			―
	Total deferred income taxes^(a)			597			485			266			171			142			63			-72
	Investment tax credit amortization			-14			-6			-8			-7			-1			-2			-1
	Income tax expense (benefit) from continuing operations			705			453			172			110			147			98			-73
	Tax expense from discontinued operations			24			―			29			―			―			―			―
	Total income tax expense (benefit) included in Consolidated Statements of Operations		$	729		$	453		$	201		$	110		$	147		$	98		$	-73

	(a)	Includes benefits of NOL carryforwards of $1,127 million at Duke Energy, $245 million at Duke Energy Carolinas, $357 million at Progress Energy, $257 million at Duke Energy Progress, $25 million at Duke Energy Florida, $99 million at Duke Energy Ohio and $205 million at Duke Energy Indiana.


			Year Ended December 31, 2011
	(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Current income taxes
	Federal		$	-37		$	-122		$	-91		$	-27		$	-60		$	-95		$	95
	State			21			30			29			21			5			1			42
	Foreign			164			―			―			―			―			―			―
	Total current income taxes			148			-92			-62			-6			-55			-94			137
	Deferred income taxes
	Federal			526			531			365			262			214			194			-38
	State			56			40			27			6			22			-2			-23
	Foreign			32			―			―			―			―			―			―
	Total deferred income taxes^(a)			614			571			392			268			236			192			-61
	Investment tax credit amortization			-10			-7			-7			-6			-1			-2			-2
	Income tax expense from continuing operations			752			472			323			256			180			96			74
	Tax benefit from discontinued operations			―			―			-3			―			―			―			―
	Total income tax expense included in Consolidated Statements of Operations		$	752		$	472		$	320		$	256		$	180		$	96		$	74

	(a)	Includes benefits of NOL carryforwards of $274 million at Duke Energy, $79 million at Duke Energy Carolinas, $213 million at Progress Energy, $54 million at Duke Energy Progress, $41 million at Duke Energy Florida and $47 million at Duke Energy Ohio.

Duke Energy Income from Continuing Operations before Income Taxes

		Years Ended December 31,
(in millions)		2013			2012			2011
Domestic			$	3,320		$	1,827		$	1,780
Foreign				600			624			685
Income from continuing operations before income taxes			$	3,920		$	2,451		$	2,465

Statutory Rate Reconciliation

The following tables present a reconciliation of income tax expense at the U.S. federal statutory tax rate to the actual tax expense from continuing operations.

		Year Ended December 31, 2013
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Income tax expense, computed at the statutory rate of 35 percent		$	1,372		$	549		$	361		$	276		$	188		$	62		$	203
State income tax, net of federal income tax effect			67			56			31			31			20			2			23
Tax differential on foreign earnings			-45			―			―			―			―			―			―
AFUDC equity income			-55			-32			-18			-15			-3			―			-5
Renewable energy production tax credits			-59			―			―			―			―			―			―
Other items, net			-19			21			-1			-4			8			11			2
Income tax expense from continuing operations		$	1,261		$	594		$	373		$	288		$	213		$	75		$	223
Effective tax rate			32.2	%		37.8	%		36.2	%		36.5	%		39.6	%		42.2	%		38.4	%


		Year Ended December 31, 2012
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Income tax expense, computed at the statutory rate of 35 percent		$	858		$	461		$	185		$	134		$	145		$	96		$	-43
State income tax, net of federal income tax effect			64			34			33			1			14			1			1
Tax differential on foreign earnings			-66			―			―			―			―			―			―
AFUDC equity income			-101			-54			-37			-24			-13			-2			-26
Renewable energy production tax credits			-25			―			―			―			―			―			―
Other items, net			-25			12			-9			-1			1			3			-5
Income tax expense (benefit) from continuing operations		$	705		$	453		$	172		$	110		$	147		$	98		$	-73
Effective tax rate			28.8	%		34.3	%		32.7	%		28.7	%		35.7	%		36	%		59.5	%


		Year Ended December 31, 2011
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Income tax expense, computed at the statutory rate of 35 percent		$	863		$	457		$	319		$	270		$	173		$	102		$	85
State income tax, net of federal income tax effect			50			46			39			18			17			-1			13
Tax differential on foreign earnings			-44			―			―			―			―			―			―
AFUDC equity income			-91			-59			-36			-25			-11			-2			-31
Renewable energy production tax credits			-21			―			―			―			―			―			―
Other items, net			-5			28			1			-7			1			-3			7
Income tax expense from continuing operations		$	752		$	472		$	323		$	256		$	180		$	96		$	74
Effective tax rate			30.5	%		36.1	%		35.6	%		33.2	%		36.3	%		33.1	%		30.6	%

Valuation allowances have been established for certain foreign and state NOL carryforwards and state income tax credits that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in Tax differential on foreign earnings and State income tax, net of federal income tax effect in the above tables.
DEFERRED TAXES

Net Deferred Income Tax Liability Components

		31-Dec-13
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Deferred credits and other liabilities		$	245		$	56		$	136		$	9		$	96		$	-13		$	9
Capital lease obligations			59			11			―			―			―			―			-2
Pension, postretirement and other employee benefits			649			18			341			119			145			23			54
Progress Energy merger purchase accounting adjustments^(a)			1,184			―			―			―			―			―			―
Tax credits and NOL carryforwards			4,307			488			1,965			396			365			165			521
Other			265			15			116			39			43			20			14
Valuation allowance			-192			―			-40			-1			―			―			―
Total deferred income tax assets			6,517			588			2,518			562			649			195			596
Investments and other assets			-1,396			-999			-209			-160			-49			-17			-7
Accelerated depreciation rates			-12,615			-4,400			-3,663			-2,528			-1,160			-1,937			-1,591
Regulatory assets and deferred debits			-3,185			-609			-1,389			-202			-1,159			-168			-117
Total deferred income tax liabilities			-17,196			-6,008			-5,261			-2,890			-2,368			-2,122			-1,715
Net deferred income tax liabilities		$	-10,679		$	-5,420		$	-2,743		$	-2,328		$	-1,719		$	-1,927		$	-1,119

(a)	Primarily related to capital lease obligations and debt fair value adjustments.

On July 23, 2013, 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.
The following table presents the expiration of tax credits and NOL carryforwards.

		31-Dec-13
(in millions)		Amount			Expiration Year
Investment Tax Credits		$	498		2029	-	2033
Alternative Minimum Tax Credits			1,028		Indefinite
Federal NOL carryforwards			2,471		2030	-	2033
State NOL carryforwards and credits^(a)			189		2014	-	2033
Foreign NOL carryforwards^(b)			121		2015	-	2033
Total tax credits and NOL carryforwards		$	4,307

(a)	A valuation allowance of $83 million has been recorded on the state NOL carryforwards, state tax credits and state capital loss carryforwards, as presented in the Net Deferred Income Tax Liability Components table.
(b)	A valuation allowance of $109 million has been recorded on the foreign NOL carryforwards, as presented in the Net Deferred Income Tax Liability Components table. Certain foreign NOL carryforwards have an indefinite expiration period.


		31-Dec-12
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Deferred credits and other liabilities		$	256		$	64		$	110		$	24		$	76		$	-10		$	22
Capital lease obligations			60			13			―			―			―			―			-1
Pension, postretirement and other employee benefits			1,320			117			712			318			257			62			94
Progress Energy merger purchase accounting adjustments^(a)			1,312			―			―			―			―			―			―
Tax credits and NOL carryforwards			3,311			447			1,536			309			91			152			340
Other			408			22			230			82			126			10			27
Valuation allowance			-226			―			-77			―			―			-1			―
Total deferred income tax assets			6,441			663			2,511			733			550			213			482
Investments and other assets			-1,093			-838			-112			-108			-6			-25			-18
Accelerated depreciation rates			-11,208			-4,289			-2,803			-2,178			-592			-1,823			-1,131
Regulatory assets and deferred debits			-3,819			-627			-1,775			-465			-1,318			-197			-185
Total deferred income tax liabilities			-16,120			-5,754			-4,690			-2,751			-1,916			-2,045			-1,334
Net deferred income tax liabilities		$	-9,679		$	-5,091		$	-2,179		$	-2,018		$	-1,366		$	-1,832		$	-852

(a)	Primarily related to capital lease obligations and debt fair value adjustments.

Classification of Deferred Tax Assets (Liabilities) in the Consolidated Balance Sheets

		31-Dec-13
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current Assets: Other		$	1,373		$	286		$	540		$	229		$	110		$	85		$	52
Investments and Other Assets: Other			45			―			―			―			―			―			―
Deferred Credits and Other Liabilities: Other			-12,097			-5,706			-3,283			-2,557			-1,829			-2,012			-1,171
Net deferred income tax liabilities		$	-10,679		$	-5,420		$	-2,743		$	-2,328		$	-1,719		$	-1,927		$	-1,119


		31-Dec-12
(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Current Assets: Other		$	732		$	90		$	359		$	144		$	152		$	21		$	1
Investments and Other Assets: Other			85			―			20			―			―			―			―
Current Liabilities: Other			-6			―			―			―			―			―			―
Deferred Credits and Other Liabilities: Other			-10,490			-5,181			-2,558			-2,162			-1,518			-1,853			-853
Net deferred income tax liabilities		$	-9,679		$	-5,091		$	-2,179		$	-2,018		$	-1,366		$	-1,832		$	-852

Deferred income taxes and foreign withholding taxes have not been provided on undistributed earnings of Duke Energy's foreign subsidiaries when such amounts are deemed to be indefinitely reinvested. The cumulative undistributed earnings as of December 31, 2013 on which Duke Energy has not provided deferred income taxes and foreign withholding taxes is approximately $2.4 billion. The amount of unrecognized deferred tax liability related to these undistributed earnings is estimated at between $300 million and $375 million.
UNRECOGNIZED TAX BENEFITS

The following tables present changes to unrecognized tax benefits.

		Year Ended December 31, 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
Unrecognized tax benefits increases (decreases)
Gross decreases — tax positions in prior periods			-231			-100			-86			-45			-37			-36			-31
Decreases due to settlements			-66			―			―			―			―			―			―
Reduction due to lapse of statute of limitations			-13			―			-13			―			1			―			―
Total changes			-310			-100			-99			-45			-36			-36			-31
Unrecognized tax benefits — December 31		$	230		$	171		$	32		$	22		$	8		$	―		$	1


		Year Ended December 31, 2012
(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		$	385		$	260		$	173		$	73		$	80		$	32		$	24
Acquisitions			128			―			―			―			―			―			―
Unrecognized tax benefits increases (decreases)
Gross increases — tax positions in prior periods			29			12			23			10			12			2			6
Gross decreases — tax positions in prior periods			-4			―			-72			-19			-52			―			―
Gross increases — current period tax positions			28			15			8			4			4			4			4
Gross decreases — current period tax positions			-9			-5			-1			-1			―			-2			-2
Decreases due to settlements			-13			-11			―			―			―			―			―
Reduction due to lapse of statute of limitations			-4			―			―			―			―			―			―
Total changes			155			11			-42			-6			-36			4			8
Unrecognized tax benefits — December 31		$	540		$	271		$	131		$	67		$	44		$	36		$	32


		Year Ended December 31, 2011
(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		$	342		$	217		$	176		$	74		$	99		$	29		$	21
Unrecognized tax benefits increases (decreases)
Gross increases — tax positions in prior periods			49			42			88			19			66			4			3
Gross decreases — tax positions in prior periods			-18			-8			-24			-14			-21			-5			-3
Gross increases — current period tax positions			16			9			9			8			1			4			3
Gross decreases — current period tax positions			―			―			-8			-4			-4			―			―
Decreases due to settlements			-4			―			-68			-10			-61			―			―
Total changes			43			43			-3			-1			-19			3			3
Unrecognized tax benefits — December 31		$	385		$	260		$	173		$	73		$	80		$	32		$	24


The following table includes additional information regarding the Duke Energy Registrants' unrecognized tax benefits. It is reasonably possible that Duke Energy and Duke Energy Carolinas will reflect an approximate $4 million reduction in unrecognized tax benefits within the next 12 months due to expected settlements. All other Duke Energy Registrants do not anticipate a material increase or decrease in unrecognized tax benefits within the next 12 months.

		31-Dec-13
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Indiana
Amount that if recognized, would affect the effective tax rate or regulatory liability^(a)			$	128		$	116		$	2		$	1		$	1		$	1
Amount that if recognized, would be recorded as a component of discontinued operations				8			―			―			―			―			―

(a)	Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana are unable to estimate the specific amounts that would affect the effective tax rate versus the regulatory liability.

OTHER TAX MATTERS

The following tables include interest recognized in the Consolidated Statements of Operations and the Consolidated Balance Sheets.

		Year Ended December 31, 2013
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Net interest income recognized related to income taxes		$	2		$	2		$	6		$	7		$	―		$	4		$	1
Interest payable related to income taxes			27			8			10			2			7			―			―


		Year Ended December 31, 2012
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Net interest income recognized related to income taxes		$	10		$	9		$	―		$	―		$	―		$	―		$	2
Net interest expense recognized related to income taxes			―			―			2			―			2			―			―
Interest receivable related to income taxes			―			7			―			―			―			―			―
Interest payable related to income taxes			7			―			17			8			9			3			1


		Year Ended December 31, 2011
(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Net interest income recognized related to income taxes		$	12		$	5		$	24		$	6		$	22		$	―		$	―
Net interest expense recognized related to income taxes			―			―			―			―			―			1			1
Interest receivable related to income taxes			8			5			―			―			―			―			―
Interest payable related to income taxes			―			―			21			8			7			3			3

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 IRS is currently auditing the federal income tax returns for years 2008 through 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 2004.

Other_Income_Expenses_Net

Other Income & Expenses, Net	12 Months Ended
Other Income & Expenses, Net	Dec. 31, 2013
Other Income and Expenses [Abstract]	'
Other Income Expenses, Net	'
	23. OTHER INCOME AND EXPENSES, NET
	The components of Other income and expenses, net on the Consolidated Statements of Operations are as follows.

		Year Ended December 31, 2013
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Interest income	$	26	$	1	$	7	$	1	$	3	$	6	$	6
	Foreign exchange losses		-18		―		―		―		―		―		―
	AFUDC equity		157		91		50		42		8		1		15
	Deferred returns		39		32		7		7		―		―		―
	Other income (expense)		58		-4		30		7		19		-3		-3
	Other income and expense, net	$	262	$	120	$	94	$	57	$	30	$	4	$	18

		Year Ended December 31, 2012
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Interest income	$	50	$	11	$	2	$	1	$	1	$	10	$	7
	Foreign exchange losses		-5		―		―		―		―		―		―
	AFUDC equity		300		154		106		69		37		6		84
	Deferred returns		24		24		―		―		―		―		―
	Other income (expense)		28		-4		22		9		1		-3		-1
	Other income and expense, net	$	397	$	185	$	130	$	79	$	39	$	13	$	90

		Year Ended December 31, 2011
	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Interest income	$	53	$	10	$	2	$	1	$	1	$	14	$	14
	Foreign exchange gains		2		―		―		―		―		―		―
	AFUDC equity		260		168		103		71		32		5		88
	Contingent value obligations mark-to-market loss		―		―		-59		―		―		―		―
	Deferred returns		10		10		―		―		―		―		―
	Other income (expense)		51		-2		6		8		-3		―		-5
	Other income and expense, net	$	376	$	186	$	52	$	80	$	30	$	19	$	97

Subsequent_Events

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	24. SUBSEQUENT EVENTS
	For information on subsequent events related to acquisitions, dispositions and sales of other assets, regulatory matters and commitments and contingencies, see Notes 2, 4 and 5.

Quarterly_Financial_Data

Quarterly Financial Data	12 Months Ended
Quarterly Financial Data	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
QuarterlyFinancialInformationTextBlock	'
	25. QUARTERLY FINANCIAL DATA (UNAUDITED)
	DUKE ENERGY

	The following table includes the results of Progress Energy beginning July 2, 2012. Quarterly EPS amounts are meant to be stand-alone calculations and are not always additive to the full-year amount due to rounding and the weighting of share issuances.

	(in millions, except per share data)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
	2013
	Operating revenues		$	5,898		$	5,879		$	6,709		$	6,112		$	24,598
	Operating income			1,215			821			1,743			1,203			4,982
	Income from continuing operations			634			345			994			686			2,659
	Net income			634			342			1,008			692			2,676
	Net income attributable to Duke Energy Corporation			634			339			1,004			688			2,665
	Earnings per share:
	Income from continuing operations attributable to Duke Energy Corporation common shareholders
		Basic	$	0.89		$	0.48		$	1.4		$	0.96		$	3.74
		Diluted	$	0.89		$	0.48		$	1.4		$	0.96		$	3.74
	Net income attributable to Duke Energy Corporation common shareholders
		Basic	$	0.89		$	0.48		$	1.42		$	0.97		$	3.77
		Diluted	$	0.89		$	0.48		$	1.42		$	0.97		$	3.76

	2012
	Operating revenues		$	3,630		$	3,577		$	6,722		$	5,695		$	19,624
	Operating income			495			786			1,078			767			3,126
	Income from continuing operations			297			449			594			406			1,746
	Net income			299			448			598			437			1,782
	Net income attributable to Duke Energy Corporation			295			444			594			435			1,768
	Earnings per share:
	Income from continuing operations attributable to Duke Energy Corporation common shareholders
		Basic	$	0.66		$	0.99		$	0.84		$	0.57		$	3.01
		Diluted	$	0.66		$	0.99		$	0.84		$	0.57		$	3.01
	Net income attributable to Duke Energy Corporation common shareholders
		Basic	$	0.66		$	0.99		$	0.85		$	0.62		$	3.07
		Diluted	$	0.66		$	0.99		$	0.85		$	0.62		$	3.07

	The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

	(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
	2013^(a)
	Costs to achieve Progress Energy merger (see Note 2)		$	-55		$	-82		$	-88		$	-72		$	-297
	Crystal River Unit 3 charges (see Note 4)			—			-295			—			-57			-352
	Harris and Levy nuclear development charges (see Note 4)			—			-87			—			—			-87
	Gain on sale of DukeNet (see Note 12)			—			—			—			105			105
	Total		$	-55		$	-464		$	-88		$	-24		$	-631

	2012
	Costs to achieve Progress Energy merger (see Note 2)		$	-8		$	-7		$	-457		$	-164		$	-636
	Edwardsport IGCC charges (see Note 4)			-420			—			-180			-28			-628
	Voluntary Opportunity Plan deferral (see Note 19)			101			—			—			—			101
	Total		$	-327		$	-7		$	-637		$	-192		$	-1,163

	(a)	Revised retail rates became effective in January for Duke Energy Florida, May for Duke Energy Ohio, June for Duke Energy Progress and September for Duke Energy Carolinas (see Note 4 for further information).

	DUKE ENERGY CAROLINAS

	(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
	2013
	Operating revenues		$	1,729		$	1,591		$	1,919		$	1,715		$	6,954
	Operating income			434			351			604			420			1,809
	Net income			244			181			342			209			976

	2012
	Operating revenues		$	1,501		$	1,616		$	1,939		$	1,609		$	6,665
	Operating income			475			386			440			216			1,517
Net income			266			211			258			130			865

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013^(a)
Costs to achieve Progress Energy merger (see Note 2)		$	-22		$	-35		$	-34		$	-29		$	-120

2012
Costs to achieve Progress Energy merger (see Note 2)		$	-4		$	-5		$	-184		$	-46		$	-239
Voluntary Opportunity Plan deferral (see Note 19)			101			—			—			—			101
Total		$	97		$	-5		$	-184		$	-46		$	-138

(a)	Revised retail rates became effective in September in both North Carolina and South Carolina (see Note 4 for further information).

PROGRESS ENERGY

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013
Operating revenues		$	2,186		$	2,281		$	2,766		$	2,300		$	9,533
Operating income			430			114			671			403			1,618
Income (loss) from continuing operations			154			-13			328			190			659
Net income (loss)			154			-17			342			196			675
Net income (loss) attributable to Parent			153			-17			341			195			672

2012
Operating revenues		$	2,102		$	2,288		$	2,788		$	2,227		$	9,405
Operating income			363			277			379			118			1,137
Income (loss) from continuing operations			141			68			154			-8			355
Net income			152			64			157			34			407
Net income attributable to Parent			150			63			155			32			400

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013^(a)
Costs to achieve the merger with Duke Energy (see Note 2)		$	-19		$	-33		$	-42		$	-28		$	-122
Crystal River Unit 3 charges (see Note 4)			―			-295			―			-57			-352
Harris and Levy nuclear development charges (see Note 4)			―			-87			―			―			-87
Total		$	-19		$	-415		$	-42		$	-85		$	-561

2012
Costs to achieve the merger with Duke Energy (see Note 2)		$	-7		$	-20		$	-217		$	-82		$	-326
Florida replacement power refund (see Note 4)			―			―			-100			―			-100
Crystal River Unit 3 charges (see Note 4)			―			―			―			-192			-192
Total		$	-7		$	-20		$	-317		$	-274		$	-618

(a)	Revised retail rates became effective in January in Florida and June in North Carolina (see Note 4 for further information).

DUKE ENERGY PROGRESS

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013
Operating revenues		$	1,216		$	1,135		$	1,430		$	1,211		$	4,992
Operating income			212			166			303			251			932
Net income			110			77			175			138			500

2012
Operating revenues		$	1,090		$	1,090		$	1,398		$	1,128		$	4,706
Operating income			107			83			172			148			510
Net income			52			31			96			93			272

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013^(a)
Costs to achieve the merger with Duke Energy (see Note 2)		$	-11		$	-22		$	-32		$	-19		$	-84
Harris nuclear development charges (see Note 4)			―			-22			―			―			-22
Total		$	-11		$	-44		$	-32		$	-19		$	-106

2012
Costs to achieve the merger with Duke Energy (see Note 2)		$	-4		$	-12		$	-180		$	-36		$	-232

(a)	Revised retail rates became effective in June in North Carolina (see Note 4 for further information).

DUKE ENERGY FLORIDA

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013
Operating revenues		$	968		$	1,142		$	1,332		$	1,085		$	4,527
Operating income (loss)			221			-53			369			151			688
Net income (loss)			110			-57			197			75			325

2012
Operating revenues		$	1,010		$	1,196		$	1,388		$	1,095		$	4,689
Operating income (loss)			255			196			207			-29			629
Net income (loss)			128			83			100			-45			266

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013^(a)
Costs to achieve the merger with Duke Energy (see Note 2)		$	-8		$	-11		$	-10		$	-9		$	-38
Crystal River Unit 3 charges (see Note 4)			―			-295			―			-57			-352
Levy nuclear development charges (see Note 4)			―			-65			―			―			-65
Total		$	-8		$	-371		$	-10		$	-66		$	-455

2012
Costs to achieve the merger with Duke Energy (see Note 2)		$	-3		$	-8		$	-37		$	-46		$	-94
Replacement power refund (see Note 4)			―			―			-100			―			-100
Crystal River Unit 3 charges (see Note 4)			―			―			―			-192			-192
Total		$	-3		$	-8		$	-137		$	-238		$	-386

(a)	Revised retail rates became effective in January (see Note 4 for further information).

DUKE ENERGY OHIO

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013
Operating revenues		$	747		$	811		$	819		$	868		$	3,245
Operating (loss) income			-17			108			116			44			251
Net (loss) income			-21			58			59			6			102

2012
Operating revenues		$	912		$	717		$	757		$	766		$	3,152
Operating income			138			95			42			74			349
Net income			74			45			14			42			175

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013^(a)
Costs to achieve Progress Energy merger (see Note 2)		$	-4		$	-4		$	-4		$	-4		$	-16

2012
Costs to achieve Progress Energy merger (see Note 2)		$	-1		$	-1		$	-22		$	-12		$	-36

(a)	Revised retail rates became effective in May (see Note 4 for further information).

DUKE ENERGY INDIANA

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013
Operating revenues		$	724		$	700		$	755		$	747		$	2,926
Operating income			181			168			203			181			733
Net income			90			82			104			82			358

2012
Operating revenues		$	688		$	685		$	718		$	626		$	2,717
Operating (loss) income			-272			134			-30			93			-75
Net (loss) income			-167			77			-19			59			-50

The following table includes unusual or infrequently occurring items in each quarter during the two most recently completed fiscal years. All amounts discussed below are pretax unless otherwise noted.

(in millions)		First Quarter			Second Quarter			Third Quarter			Fourth Quarter			Total
2013
Costs to achieve Progress Energy merger (see Note 2)		$	-4		$	-5		$	-5		$	-5		$	-19

2012
Costs to achieve Progress Energy merger (see Note 2)		$	-1		$	-1		$	-21		$	-11		$	-34
Edwardsport IGCC charges (see Note 4)			-420			—			-180			-28			-628
Total		$	-421		$	-1		$	-201		$	-39		$	-662

Organization_and_Basis_of_Pres

Organization and Basis of Presentation (Policy)	12 Months Ended
Organization and Basis of Presentation (Policy)	Dec. 31, 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 U.S. and Latin America primarily through its direct and indirect subsidiaries. Duke Energy's subsidiaries include its wholly owned 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.
	On July 2, 2012, Duke Energy merged with Progress Energy, with Duke Energy continuing as the surviving corporation. Progress Energy became a subsidiary of Duke Energy and Progress Energy's regulated utility subsidiaries, Duke Energy Progress (formerly Carolina Power & Light Company d/b/a Progress Energy Carolinas, Inc.) and Duke Energy Florida (formerly Florida Power Corporation d/b/a Progress Energy Florida, Inc.), became indirect subsidiaries of Duke Energy. Duke Energy's consolidated financial statements include Progress Energy, Duke Energy Progress and Duke Energy Florida activity beginning July 2, 2012. The impacts of acquisition accounting from Progress Energy's merger with Duke Energy were recorded by Duke Energy and were not reflected on the financial statements of Progress Energy, Duke Energy Progress and Duke Energy Florida. See Note 2 for additional information regarding the merger. On July 2, 2012, just prior to the close of the merger, Duke Energy executed a one-for-three reverse stock split with respect to the issued and outstanding shares of Duke Energy common stock. All per-share amounts included in this Form 10-K are presented as if the stock split had been effective from the beginning of the earliest period presented.
	The information in these combined notes relates to each of the Duke Energy Registrants as noted in the Index to the 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.
	These Consolidated Financial Statements include, after eliminating intercompany transactions and balances, the accounts of the Duke Energy Registrants and subsidiaries where the respective Duke Energy Registrants have control. These Consolidated Financial Statements also reflect the Duke Energy Registrants' proportionate share of jointly owned generation and transmission facilities.
	Duke Energy Carolinas 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 Carolinas is subject to the regulatory provisions of the North Carolina Utilities Commission (NCUC), Public Service Commission of South Carolina (PSCSC), U.S. Nuclear Regulatory Commission (NRC) and FERC. Substantially all of Duke Energy Carolinas' operations qualify for regulatory accounting.
	Progress Energy is a public utility 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. Substantially all of Progress Energy's operations qualify for regulatory accounting.
	Duke Energy Progress 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, PSCSC, NRC and FERC. Substantially all of Duke Energy Progress' operations qualify for regulatory accounting.
	Duke Energy Florida 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 jurisdiction of the Florida Public Service Commission (FPSC), NRC and FERC. Substantially all of Duke Energy Florida's operations qualify for regulatory accounting.
	Duke Energy Ohio is a 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's principal lines of business include transmission and distribution of electricity and the sale of and/or transportation of natural gas. Duke Energy Ohio also generates and sells power into wholesale energy markets. 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), Kentucky Public Service Commission (KPSC) and FERC. Duke Energy Ohio applies regulatory accounting to a portion of its operations.
	Duke Energy Indiana 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 qualify for regulatory accounting.
	Certain prior year amounts have been reclassified to conform to the current year presentation.
Use Of Estimates	'
	Use of Estimates
	In preparing financial statements that conform to generally accepted accounting principles (GAAP) in the U.S., the Duke Energy Registrants 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.
Regulatory Accounting	'
	Regulatory Accounting
	The majority of the Duke Energy Registrants' operations are subject to price regulation for the sale of electricity and gas by state utility commissions or FERC. When prices are set on the basis of specific costs of the regulated operations and an effective franchise is in place such that sufficient gas or electric services can be sold to recover those costs, the Duke Energy Registrants apply regulatory accounting. Regulatory accounting changes the timing of the recognition of costs or revenues relative to a company that does not apply regulatory accounting. As a result, Regulatory assets and Regulatory liabilities are recognized on the Consolidated Balance Sheets. Regulatory assets and liabilities are amortized consistent with the treatment of the related cost in the ratemaking process. See Note 4 for further information.

Energy Purchases, Fuel Costs And Fuel Cost Deferrals	'
	Regulated Fuel Costs and Purchased Power
	The Duke Energy Registrants utilize cost-tracking mechanisms, commonly referred to as fuel adjustment clauses. These clauses allow for the recovery of fuel and fuel-related costs and portions of purchased power costs through surcharges on customer rates. The difference between the costs incurred and the surcharge revenues is recorded as an adjustment to Fuel used in electric generation and purchased power — regulated or Operating Revenues – Regulated electric on the Consolidated Statements of Operations with an off-setting impact on regulatory assets or liabilities.

Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	All highly liquid investments with maturities of three months or less at the date of acquisition are considered cash equivalents. At December 31, 2013, $1,086 million of Duke Energy's total cash and cash equivalents is held by entities domiciled in foreign jurisdictions and is forecasted to be used to fund international operations and investments.
Restricted Cash	'
	Restricted Cash
	The Duke Energy Registrants have restricted cash related primarily to collateral assets, escrow deposits, and variable interest entities (VIEs). Restricted cash balances are reflected in Other within Current Assets and in Other within Investments and Other Assets on the Consolidated Balance Sheets. At December 31, 2013 and 2012, Duke Energy had restricted cash totaling $307 million and $574 million, respectively.
Inventory	'
	Inventory
	Inventory is used for operations and is recorded primarily using the average cost method. Inventory related to regulated operations is valued at historical cost. Inventory related to nonregulated operations is valued at the lower of cost or market. Materials and supplies are recorded as inventory when purchased and subsequently charged to expense or capitalized to property, plant and equipment when installed. Reserves are established for excess and obsolete inventory. The components of inventory are presented in the tables below.
Investments In Debt And Equity Securities	'
	Investments in Debt and Equity Securities
	The Duke Energy Registrants classify investments into two categories — trading and available-for-sale. Both categories are recorded at fair value on the Consolidated Balance Sheets. Realized and unrealized gains and losses on trading securities are included in earnings. For certain investments of regulated operations such as the Nuclear Decommissioning Trust Fund (NDTF), realized and unrealized gains and losses (including any other-than-temporary impairments) on available-for-sale securities are recorded as a regulatory asset or liability. Otherwise, unrealized gains and losses are included in Accumulated Other Comprehensive Income (AOCI), unless other-than-temporarily impaired. Other-than-temporary impairments for equity securities and the credit loss portion of debt securities of nonregulated operations are included in earnings. Investments in debt and equity securities are classified as either current or noncurrent based on management's intent and ability to sell these securities, taking into consideration current market liquidity. See Note 15 for further information.
Goodwill	'
	Goodwill and Intangible Assets
	Goodwill
	Duke Energy, Progress Energy and Duke Energy Ohio perform annual goodwill impairment tests as of August 31 each year at the reporting unit level, which is determined to be an operating segment or one level below. Duke Energy, Progress Energy and Duke Energy Ohio update these tests 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.
	In 2012, Progress Energy changed its goodwill impairment testing date from October 31 to August 31 to better align its annual goodwill impairment testing procedure with those of Duke Energy. The change had no impact on goodwill. Neither the change in the goodwill impairment testing date nor the merger resulted in any changes to the Progress Energy reporting units.
	Intangible Assets
	Intangible assets are included in Other in Investments and Other Assets on the Consolidated Balance Sheets. Generally, intangible assets are amortized using an amortization method that reflects the pattern in which the economic benefits of the intangible asset are consumed, or on a straight-line basis if that pattern is not readily determinable. Amortization of intangibles is reflected in Depreciation and amortization in the Consolidated Statements of Operations. Intangible assets are subject to impairment testing and if impaired, the carrying value is accordingly reduced.
	Emission allowances permit the holder of the allowance to emit certain gaseous by-products of fossil fuel combustion, including sulfur dioxide (SO2) and nitrogen oxide (NOx). Allowances are issued by the U.S. Environmental Protection Agency (EPA) at zero cost and may also be bought and sold via third-party transactions. Allowances allocated to or acquired by the Duke Energy Registrants are held primarily for consumption. Carrying amounts for emission allowances are based on the cost to acquire the allowances or, in the case of a business combination, on the fair value assigned in the allocation of the purchase price of the acquired business.
	Renewable energy certificates are used to measure compliance with renewable energy standards and are held primarily for consumption.
	See Note 11 for further information.

Long-Lived Asset Impairments	'
	Long-Lived Asset Impairments
	The Duke Energy Registrants evaluate long-lived assets, excluding goodwill, for impairment when circumstances indicate the carrying value of those assets may not be recoverable. An impairment exists when a long-lived asset's carrying value exceeds the estimated undiscounted cash flows expected to result from the use and eventual disposition of the asset. The estimated cash flows may be based on alternative expected outcomes that are probability weighted. If the carrying value of the long-lived asset is not recoverable based on these estimated future undiscounted cash flows, the carrying value of the asset is written-down to its then-current estimated fair value and an impairment charge is recognized.
	The Duke Energy Registrants assess fair value of long-lived assets using various methods, including recent comparable third-party sales, internally developed discounted cash flow analysis and analysis from outside advisors. Significant changes in commodity prices, the condition of an asset or management's interest in selling the asset are generally viewed as triggering events to re-assess cash flows. See Note 11 for further information.
Property, Plant and Equipment	'
	Property, Plant and Equipment
	Property, plant and equipment are stated at the lower of depreciated historical cost net of any disallowances or fair value, if impaired. The Duke Energy Registrants capitalize all construction-related direct labor and material costs, as well as indirect construction costs such as general engineering, taxes and financing costs. See “Allowance for Funds Used During Construction (AFUDC) and Interest Capitalized” for information on capitalized financing costs. Costs of renewals and betterments that extend the useful life of property, plant and equipment are also capitalized. The cost of repairs, replacements and major maintenance projects, which do not extend the useful life or increase the expected output of the asset, are expensed as incurred. Depreciation is generally computed over the estimated useful life of the asset using the composite straight-line method. Depreciation studies are conducted periodically to update composite rates and are approved by state utility commissions and/or the FERC when required. The composite weighted-average depreciation rates, excluding nuclear fuel, are included in the table that follows.
	In general, when the Duke Energy Registrants retire regulated property, plant and equipment, original cost plus the cost of retirement, less salvage value, is charged to accumulated depreciation. However, when it becomes probable a regulated asset will be retired substantially in advance of its original expected useful life or is abandoned, the cost of the asset and the corresponding accumulated depreciation is recognized as a separate asset. If the asset is still in operation, the net amount is classified as Generation facilities to be retired, net on the Consolidated Balance Sheets. If the asset is no longer operating, the net amount is classified in Regulatory Assets on the Consolidated Balance Sheets. The carrying value of the asset is based on historical cost if the Duke Energy Registrants are allowed to recover the remaining net book value and a return equal to at least the incremental borrowing rate. If not, an impairment is recognized to the extent the net book value of the asset exceeds the present value of future revenues discounted at the incremental borrowing rate.
	When the Duke Energy Registrants sell entire regulated operating units, or retire or sell nonregulated properties, the original cost and accumulated depreciation and amortization balances are removed from Property, Plant and Equipment on the Consolidated Balance Sheets. Any gain or loss is recorded in earnings, unless otherwise required by the applicable regulatory body.
	See Note 10 for further information.
Nuclear Fuel	'
	Nuclear Fuel
	Nuclear fuel is classified as Property, Plant and Equipment on the Consolidated Balance Sheets. Nuclear fuel in the front-end fuel processing phase is considered work in progress and not amortized until placed in service. Amortization of nuclear fuel is included within Fuel used in electric generation and purchased power – regulated in the Consolidated Statements of Operations. Amortization is recorded using the units-of-production method.
AFUDC And Interest Capitalized	'
	Allowance for Funds Used During Construction (AFUDC) and Interest Capitalized
	For regulated operations, the debt and equity costs of financing the construction of property, plant and equipment are reflected as AFUDC and capitalized as a component of the cost of property, plant and equipment. AFUDC equity is reported on the Consolidated Statements of Operations as non-cash income in Other income and expenses, net. AFUDC debt is reported as a non-cash offset to Interest Expense. After construction is completed, the Duke Energy Registrants are permitted to recover these costs through their inclusion in rate base and the corresponding subsequent depreciation or amortization of those regulated assets.
	AFUDC equity, a permanent difference for income taxes, reduces the effective tax rate when capitalized and increases the effective tax rate when depreciated or amortized. See Note 22 for additional information.
	For nonregulated operations, interest is capitalized during the construction phase with an offsetting non-cash credit to Interest Expense on the Consolidated Statements of Operations.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	Asset retirement obligations are recognized for legal obligations associated with the retirement of property, plant and equipment. Substantially all asset retirement obligations are related to regulated operations. When recording an asset retirement obligation, the present value of the projected liability is recognized in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is accreted over time. The present value of the liability is added to the cost of the associated asset and depreciated over the remaining life of the asset.
	The present value of the initial obligation and subsequent updates are based on discounted cash flows, which include estimates regarding timing of future cash flows, selection of discount rates and cost escalation rates, among other factors. These estimates are subject to change. Depreciation expense is adjusted prospectively for any changes to the carrying amount of the associated asset. The Duke Energy Registrants receive amounts to fund the cost of the asset retirement obligation for regulated operations through a combination of regulated revenues and NDTF. As a result, the net of amounts recovered in regulated revenues, earnings on the NDTF, accretion expense and depreciation of the associated asset is deferred as a regulatory asset or liability.
	Obligations for nuclear decommissioning are based on site-specific cost studies. Duke Energy Carolinas and Duke Energy Progress assume prompt dismantlement of the nuclear facilities after operations are ceased. Duke Energy Florida assumes Crystal River Nuclear Station – Unit 3 (Crystal River Unit 3) will be placed into a safe storage configuration until eventual dismantlement begins in approximately 60 years. Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida also assume that spent fuel will be stored on site until such time that it can be transferred to a U.S. Department of Energy (DOE) facility.
	See Note 9 for further information.
Unbilled Revenue	'
	Revenue Recognition and Unbilled Revenue
	Revenues on sales of electricity and gas are recognized when service is provided. Unbilled revenues are recognized by applying customer billing rates to the estimated volumes of energy delivered but not yet billed. Unbilled revenues can vary significantly from period to period as a result of seasonality, weather, customer usage patterns and meter reading schedules.
	Unbilled revenues are included within Receivables and Restricted receivables of variable interest entities on the Consolidated Balance Sheets as shown in the following table.
Accounting For Risk Management, Hedging Activities And Financial Instruments	'
	Derivatives and Hedging
	Derivative and non-derivative instruments may be used in connection with commodity price, interest rate and foreign currency risk management activities, including swaps, futures, forwards and options. All derivative instruments except those that qualify for the normal purchase/normal sale (NPNS) exception are recorded on the Consolidated Balance Sheets at their fair value. Qualifying derivative instruments may be designated as either cash flow hedges or fair value hedges. Other derivative instruments (undesignated contracts) either have not been designated or do not qualify as hedges. The effective portion of the change in the fair value of cash flow hedges is recorded in AOCI. The effective portion of the change in the fair value of a fair value hedge is offset in net income by changes in the hedged item. For activity subject to regulatory accounting, gains and losses on derivative contracts are reflected as regulatory assets or liabilities and not as other comprehensive income or current period income. As a result, changes in fair value of these derivatives have no immediate earnings impact.
	Formal documentation, including transaction type and risk management strategy, is maintained for all contracts accounted for as a hedge. At inception and at least every three months thereafter, the hedge contract is assessed to see if it is highly effective in offsetting changes in cash flows or fair values of hedged items.
	See Note 14 for further information.
Captive Insurance Reserves	'
	Captive Insurance Reserves
	Duke Energy has captive insurance subsidiaries that provide coverage, on an indemnity basis, to the Subsidiary Registrants as well as certain third parties, on a limited basis, for various business risks and losses, such as property, workers' compensation and general liability. Liabilities include provisions for estimated losses incurred but not yet reported (IBNR), as well as estimated provisions for known claims. IBNR reserve estimates are primarily based upon historical loss experience, industry data and other actuarial assumptions. Reserve estimates are adjusted in future periods as actual losses differ from experience.
	Duke Energy, through its captive insurance entities, also has reinsurance coverage with third parties for certain losses above a per occurrence and/or aggregate retention. Receivables for reinsurance coverage are recognized when realization is deemed probable.
Unamortized Debt Premium, Discount And Expense	'
	Unamortized Debt Premium, Discount and Expense
	Premiums, discounts and expenses incurred with the issuance of outstanding long-term debt are amortized over the term of the debt issue. Call premiums and unamortized expenses associated with refinancing higher-cost debt obligations used to finance regulated assets are amortized. Amortization expense is recorded as Interest Expense in the Consolidated Statements of Operations and is reflected as Depreciation, amortization and accretion within Net cash provided by operating activities on the Consolidated Statements of Cash Flows.
Loss Contingencies And Environmental Liabilities	'
	Loss Contingencies and Environmental Liabilities
	Contingent losses are recorded when it is probable a loss has occurred and can be reasonably estimated. When a range of the probable loss exists and no amount within the range is a better estimate than any other amount, the minimum amount in the range is recorded. Unless otherwise required by GAAP, legal fees are expensed as incurred.
	Environmental liabilities are recorded on an undiscounted basis when environmental remediation or other liabilities becomes probable and can be reasonably estimated. Environmental expenditures related to past operations that do not generate current or future revenues are expensed. Environmental expenditures related to operations that generate current or future revenues are expensed or capitalized, as appropriate. Certain environmental expenditures receive regulatory accounting treatment and are recorded as regulatory assets.
	See Notes 4 and 5 for further information.
Pension And Other Post-Retirement Benefit Plans	'
	Pension and Other Post-Retirement Benefit Plans
	Duke Energy maintains qualified, non-qualified and other post-retirement benefit plans. Eligible employees of the Subsidiary Registrants participate in the respective qualified, non-qualified and other post-retirement benefit plans and are allocated their proportionate share of benefit costs. See Note 21 for further information, including significant accounting policies associated with these plans.

Severance And Special Termination Benefits	'
	Severance and Special Termination Benefits
	Duke Energy has an ongoing severance plan under which, in general, the longer a terminated employee worked prior to termination the greater the amount of severance benefits. A liability for involuntary severance is recorded once an involuntary severance plan is committed to by management, or sooner, if involuntary severances are probable and can be reasonably estimated. For involuntary severance benefits incremental to its ongoing severance plan benefits, the fair value of the obligation is expensed at the communication date if there are no future service requirements, or over the required future service period. From time to time, Duke Energy offers special termination benefits under voluntary severance programs. Special termination benefits are recorded immediately upon employee acceptance absent a significant retention period. Otherwise, the cost is recorded over the remaining service period. Employee acceptance of voluntary severance benefits is determined by management based on the facts and circumstances of the benefits being offered. See Note 19 for further information.
Guarantees	'
	Guarantees
	Liabilities are recognized at the time of issuance or material modification of a guarantee for the estimated fair value of the obligation it assumes. Fair value is estimated using a probability-weighted approach. The obligation is reduced over the term of the guarantee or related contract in a systematic and rational method as risk is reduced. Any additional contingent loss for guarantee contracts subsequent to the initial recognition of a liability is accounted for and recognized at the time a loss is probable and can be reasonably estimated. See Note 7 for further information.
Stock-based Compensation	'
	Stock-Based Compensation
	Stock-based compensation represents costs related to stock-based awards granted to employees. Duke Energy recognizes stock-based compensation based upon the estimated fair value of awards, net of estimated forfeitures at the date of issuance. The recognition period for these costs begin at either the applicable service inception date or grant date and continues throughout the requisite service period, or for certain share-based awards until the employee becomes retirement eligible, if earlier. Compensation cost is recognized as expense or capitalized as a component of property, plant and equipment. See Note 20 for further information.
Income Taxes	'
	Income Taxes
	Duke Energy and its subsidiaries file a consolidated federal income tax return and other state and foreign jurisdictional returns. The Subsidiary Registrants entered into a tax-sharing agreement with Duke Energy and income taxes recorded represent amounts the Subsidiary Registrants would incur as separate C-Corporations. Deferred income taxes have been provided for temporary differences between GAAP and tax bases of assets and liabilities because the differences create taxable or tax-deductible amounts for future periods. Deferred taxes are not provided on translation gains and losses when earnings of a foreign operation are expected to be indefinitely reinvested. Investment tax credits (ITC) associated with regulated operations are deferred and amortized as a reduction of income tax expense over the estimated useful lives of the related properties.
	Positions taken or expected to be taken on tax returns, including the decision to exclude certain income or transactions from a return, are recognized in the financial statements when it is more likely than not the tax position can be sustained based solely on the technical merits of the position. The largest amount of tax benefit that is greater than 50 percent likely of being effectively settled is recorded. Management considers a tax position effectively settled when: (i) the taxing authority has completed its examination procedures, including all appeals and administrative reviews; (ii) the Duke Energy Registrants do not intend to appeal or litigate the tax position included in the completed examination; and (iii) it is remote the taxing authority would examine or re-examine the tax position. The amount of a tax return position that is not recognized in the financial statements is disclosed as an unrecognized tax benefit. These unrecognized tax benefits may impact the financial statements through increasing income taxes payable, reducing income tax refunds receivable or changing deferred taxes.
	Tax-related interest and penalties are recorded in Interest Expense and Other Income and Expenses, net, in the Consolidated Statements of Operations.
	See Note 22 for further information.
Accounting For Renewable Energy Tax Credits And Grants	'
	Accounting for Renewable Energy Tax Credits and Grants
	When Duke Energy elects either an ITC or a cash grant on wind or solar facilities, it reduces the basis of the property recorded on the Consolidated Balance Sheets by the amount of the ITC or cash grant and, therefore, the ITC or grant benefit is recognized through reduced depreciation expense. Additionally, certain tax credits and government grants received provide for initial tax depreciable base in excess of the book carrying value equal to one half of the ITC or government grant. Deferred tax benefits are recorded as a reduction to income tax expense in the period that the basis difference is created.
Excise Taxes	'
	Excise Taxes
	Certain excise taxes levied by state or local governments are required to be paid even if not collected from the customer. These taxes are recognized on a gross basis. Otherwise, the taxes are accounted for net. Excise taxes accounted for on a gross basis as Property and other taxes in the Consolidated Statements of Operations were as follows.
Foreign Currency Transaction	'
	Foreign Currency Translation
	The local currencies of most of Duke Energy's foreign operations have been determined to be their functional currencies. However, certain foreign operations' functional currency has been determined to be the U.S. Dollar, based on an assessment of the economic circumstances of the foreign operation. Assets and liabilities of foreign operations whose functional currency is not the U.S. Dollar, are translated into U.S. Dollars at the exchange rates in effect at period end. Translation adjustments resulting from changes in exchange rates are included in AOCI. Revenue and expense accounts are translated at average exchange rates during the year. Gains and losses arising from balances and transactions denominated in currencies other than the local currency are included in the results of operations when they occur.
Dividend Restrictions And Unappropriated Retained Earnings	'
	Dividend Restrictions and Unappropriated Retained Earnings
	Duke Energy does not have any legal, regulatory or other restrictions on paying common stock dividends to shareholders. However, as further described in Note 4, due to conditions established by regulators in conjunction with merger transaction approvals, Duke Energy Carolinas, Duke Energy Progress, Duke Energy Ohio and Duke Energy Indiana have restrictions on paying dividends or otherwise advancing funds to Duke Energy. At December 31, 2013 and 2012, an insignificant amount of Duke Energy's consolidated Retained earnings balance represents undistributed earnings of equity method investments.
New Accounting Standards	'
	New Accounting Standards
	The new accounting standards that were adopted for 2013, 2012 and 2011 had no significant impact on the presentation or results of operations, cash flows or financial position of the Duke Energy Registrants. Disclosures have been enhanced to provide a discussion and tables on derivative contracts subject to enforceable master netting agreements and a table of quantitative disclosures about unobservable inputs. See Notes 14 and 16 for further information.
	There are no Accounting Standards Updates that have been issued but not yet adopted as of December 31, 2013, that are expected to significantly impact the presentation or results of operations, cash flows or financial position or disclosures of the Duke Energy Registrants.
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, including receivables for unbilled revenues, to an affiliate, Cinergy Receivables Company, LLC (CRC) and account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 17 for further information. These receivables for unbilled revenues are 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, including receivables for unbilled revenues, to an affiliate, Cinergy Receivables Company, LLC (CRC) and account for the transfers of receivables as sales. Accordingly, the receivables sold are not reflected on the Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 17 for further information. These receivables for unbilled revenues are shown in the table below.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Tables)	12 Months Ended
Summary of Significant Accounting Policies (Tables)	Dec. 31, 2013																						Dec. 31, 2012
Organization And Basis Of Presentation [Line Items]	'																						'
Components Of Inventory	'																						'
			31-Dec-13																						31-Dec-12
	(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
	Materials and supplies		$	1,901		$	654		$	854		$	567		$	287		$	117		$	193	Materials and supplies		$	1,691		$	535		$	768		$	499		$	269		$	135		$	161
	Coal held for electric generation			1,018			374			334			187			147			65			238	Coal held for electric generation			1,187			488			392			232			160			82			216
	Oil, gas and other fuel held for electric generation			331			37			236			99			137			47			3	Oil, gas and other fuel held for electric generation			345			39			281			97			184			10			3
	Total inventory		$	3,250		$	1,065		$	1,424		$	853		$	571		$	229		$	434	Total inventory		$	3,223		$	1,062		$	1,441		$	828		$	613		$	227		$	380

Schedule Of Composite Weighted-Average Depreciation Rates	'																						'

			Years Ended December 31,																										31-Dec-12
			2013			2012			2011														(in millions)		Estimated Useful Life (Years)					Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Duke Energy		2.8	%		2.9	%		3.2	%													Land						$	1,368	$	378	$	618	$	380	$	239	$	136	$	90
	Duke Energy Carolinas		2.8	%		2.8	%		2.6	%													Plant - Regulated
	Progress Energy		2.5	%		2.6	%		2.3	%														Electric generation, distribution and transmission	2	-	138			73,181		29,269		30,250		18,009		12,041		3,774		8,622
	Duke Energy Progress		2.5	%		2.7	%		2.1	%														Natural gas transmission and distribution	12	-	60			2,026		―		―		―		―		2,026		―
	Duke Energy Florida		2.4	%		2.5	%		2.4	%														Other buildings and improvements	2	-	100			1,319		444		609		283		318		125		149
	Duke Energy Ohio		3.3	%		3.2	%		3.5	%													Plant - Nonregulated
	Duke Energy Indiana		2.8	%		3.3	%		3.4	%														Electric generation, distribution and transmission	2	-	100			6,055		―		―		―		―		3,870		―
																								Other buildings and improvements	9	-	90			2,940		―		―		―		―		191		―
																							Nuclear fuel							2,127		1,277		850		850		―		―		―
							31-Dec-13																Equipment		1	-	34			1,448		279		604		336		90		255		141
	(in millions)		Estimated Useful Life (Years)					Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana			Construction in process							6,655		1,996		1,424		946		474		204		2,836
	Land						$	1,481	$	397	$	705	$	383	$	321	$	137	$	105			Other		5	-	60			3,272		547		791		380		270		243		174
	Plant - Regulated																						Total property, plant and equipment^(a)(d)							100,391		34,190		35,146		21,184		13,432		10,824		12,012
		Electric generation, distribution and transmission	2	-	125			78,272		30,018		31,792		19,190		12,601		3,925		11,594			Total accumulated depreciation - regulated^(b)(c)(d)							-29,471		-11,437		-12,512		-8,185		-4,072		-1,995		-3,692
		Natural gas transmission and distribution	12	-	67			2,138		―		―		―		―		2,138		―			Total accumulated depreciation - nonregulated^(c)(d)							-2,498		―		―		―		―		-703		―
		Other buildings and improvements	2	-	100			1,397		447		610		282		315		190		159			Generation facilities to be retired, net							136		73		63		63		―		―		―
	Plant - Nonregulated																						Total net property, plant and equipment						$	68,558	$	22,826	$	22,697	$	13,062	$	9,360	$	8,126	$	8,320
		Electric generation, distribution and transmission	2	-	100			6,267		―		―		―		―		4,017		―
		Other buildings and improvements	9	-	100			2,512		―		―		―		―		5		―			(a)	Includes capitalized leases of $1,844 million, $53 million, $339 million, $150 million, $189 million, $86 million, and $28 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $49 million, an insignificant amount and $48 million, respectively, of accumulated amortization of capitalized leases.
	Nuclear fuel							2,458		1,446		1,012		1,012		―		―		―			(b)	Includes $857 million, $557 million, $300 million and $300 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.
	Equipment		1	-	33			1,557		287		621		357		94		317		146			(c)	Includes accumulated amortization of capitalized leases of $34 million, $3 million, $12 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.
	Construction in process							3,595		1,741		873		631		238		166		307			(d)	Includes gross property, plant and equipment cost of consolidated VIEs of $1,558 million and accumulated depreciation of consolidated VIEs of $103 million at Duke Energy.
	Other		5	-	33			3,438		570		867		418		294		248		178
	Total property, plant and equipment^(a)(d)							103,115		34,906		36,480		22,273		13,863		11,143		12,489
	Total accumulated depreciation - regulated^(b)(c)(d)							-31,659		-11,894		-13,098		-8,623		-4,252		-2,160		-3,913
	Total accumulated depreciation - nonregulated^(c)(d)							-1,966		―		―		―		―		-748		―
	Total net property, plant and equipment						$	69,490	$	23,012	$	23,382	$	13,650	$	9,611	$	8,235	$	8,576

	(a)	Includes capitalized leases of $1,606 million, $53 million, $328 million, $148 million, $180 million, $96 million, and $30 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $60 million, an insignificant amount and $57 million, respectively, of accumulated amortization of capitalized leases.
	(b)	Includes $1,118 million, $681 million, $438 million and $438 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.
	(c)	Includes accumulated amortization of capitalized leases of $40 million, $4 million, $21 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.
	(d)	Includes gross property, plant and equipment cost of consolidated VIEs of $1,678 million and accumulated depreciation of consolidated VIEs of $175 million at Duke Energy.

Schedule of Excise Taxes	'																						'

			Years Ended December 31,
	(in millions)			2013			2012			2011
	Duke Energy		$	602		$	466		$	293
	Duke Energy Carolinas			164			161			153
	Progress Energy			304			317			315
	Duke Energy Progress			115			113			110
	Duke Energy Florida			189			205			205
	Duke Energy Ohio			105			102			109
	Duke Energy Indiana			29			33			31

	On July 23, 2013, North Carolina House Bill 998 (HB 998) was signed into law. HB 998 repeals the utility franchise tax effective July 1, 2014. The utility franchise tax was 3.22 percent gross receipts tax on sales of electricity. The result of this change in law will be an annual reduction in excise taxes of approximately $160 million for Duke Energy Carolinas and approximately $110 million for Duke Energy Progress. HB 998 also increases sales tax on electricity from 3 percent to 7 percent effective July 1, 2014. HB 998 requires the NCUC to adjust retail electric rates for the elimination of the utility franchise tax, changes due to the increase in sales tax on electricity, and the resulting change in liability of utility companies under the general franchise tax.

Schedule Of Unbilled Revenues With Restricted Receivables	'																						'

			December 31,
	(in millions)		2013			2012
	Duke Energy		$	937		$	920
	Duke Energy Carolinas			323			315
	Progress Energy			189			187
	Duke Energy Progress			120			112
	Duke Energy Florida			69			74
	Duke Energy Ohio			55			47
	Duke Energy Indiana			5			3

Schedule of Receivable, Allowance for Doubtful Accounts	'																						'
	Allowance for Doubtful Accounts

	Allowances for doubtful accounts are presented in the following table.

			December 31,
	(in millions)		2013			2012			2011
	Allowance for Doubtful Accounts
	Duke Energy		$	30		$	34		$	35
	Duke Energy Carolinas			3			3			3
	Progress Energy			14			16			27
	Duke Energy Progress			10			9			9
	Duke Energy Florida			4			7			18
	Duke Energy Ohio			2			2			16
	Duke Energy Indiana			1			1			1
	Allowance for Doubtful Accounts - VIEs
	Duke Energy		$	43		$	44		$	40
	Duke Energy Carolinas			6			6			6

Schedule of Current and Noncurrent Assets and Liabilities	'																						'

					December 31,
	(in millions)		Location		2013			2012
	Duke Energy
	Accrued compensation		Current Liabilities		$	621		$	725
	Duke Energy Carolinas
	Accrued compensation		Current Liabilities		$	198		$	203
	Collateral liabilities		Current Liabilities			120			105
	Progress Energy
	Customer deposits		Current Liabilities		$	349		$	342
	Accrued compensation		Current Liabilities			214			304
	Derivative liabilities		Current Liabilities			—			221
	Duke Energy Progress
	Customer deposits		Current Liabilities		$	129		$	120
	Accrued compensation		Current Liabilities			121			160
	Duke Energy Florida
	Customer deposits		Current Liabilities		$	220		$	222
	Accrued compensation		Current Liabilities			65			95
	Derivative liabilities		Current Liabilities			—			127
	Duke Energy Ohio
	Collateral assets		Current Assets		$	122		$	99
	Duke Energy Indiana
	Federal income taxes receivable		Current Assets		$	56		$	—
	Accrued compensation^(a)		Current Liabilities			25			23
	Collateral liabilities^(a)		Current Liabilities			40			37
	Derivative liabilities		Current Liabilities			—			63

	(a)	Does not exceed 5 percent of Total current liabilities on the Consolidated Balance Sheets at December 31, 2012.

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

			December 31,
	(in millions)		2013			2012
	Duke Energy Ohio		$	89		$	90
	Duke Energy Indiana			144			132

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

			December 31,
	(in millions)		2013			2012
	Duke Energy Ohio		$	89		$	90
	Duke Energy Indiana			144			132

Acquisitions_Dispositions_and_1

Acquisitions, Dispositions and Sales of Other Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Significant Acquisitions and Disposals [Line Items]	'
Accounting Charges Related to the Merger Consummation	'

	(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	FERC Mitigation	$	117	$	46	$	71	$	71	$	―	$	―	$	―
	Severance costs		196		63		82		55		27		21		18
	Community support, charitable contributions and other		169		79		74		63		11		7		6
	Total	$	482	$	188	$	227	$	189	$	38	$	28	$	24

Schedule of Purchase Price Calculation	'

	(dollars in millions, except per share amounts; shares in thousands)
	Progress Energy common shares outstanding at July 2, 2012		296,116
	Exchange ratio		0.87083
	Duke Energy common shares issued for Progress Energy common shares outstanding		257,867
	Closing price of Duke Energy common shares on July 2, 2012	$	69.84
	Purchase price for common stock	$	18,009
	Fair value of outstanding earned stock compensation awards		62
	Total purchase price	$	18,071

Schedule of Purchase Price Allocation	'

	(in millions)
	Current assets	$	3,204
	Property, plant and equipment		23,141
	Goodwill		12,469
	Other long-term assets		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	'

				Years Ended December 31,
	(in millions, except per share amounts)			2012		2011
	Revenues			$	23,976	$	23,445
	Net Income Attributable to Duke Energy Corporation				2,417		2,397
	Basic and Diluted Earnings Per Share				3.43		3.41

Business_Segments_Tables

Business Segments (Tables)	12 Months Ended
Business Segments (Tables)	Dec. 31, 2013																				Dec. 31, 2012																				Dec. 31, 2011
Segment Reporting Information [Line Items]	'																				'																				'
Business Segment Data	'																				'																				'
			Year Ended December 31, 2013
											Total												Year Ended December 31, 2012																				Year Ended December 31, 2011
			Regulated		International			Commercial			Reportable																				Total
	(in millions)		Utilities		Energy			Power			Segments			Other			Eliminations		Total				Regulated		International			Commercial			Reportable												Regulated		International			Commercial Power			Total Reportable
	Unaffiliated revenues^(a)(b)(c)		$	20,871	$	1,546		$	2,106		$	24,523		$	75		$	―	$	24,598	(in millions)		Utilities		Energy			Power			Segments			Other			Eliminations		Total		(in millions)		Utilities		Energy			Energy			Segments^(a)		Other		Eliminations		Total
	Intersegment revenues			39		―			39			78			88			-166		―	Unaffiliated revenues		$	16,042	$	1,549		$	2,020		$	19,611		$	13		$	―	$	19,624	Unaffiliated revenues		$	10,586	$	1,467		$	2,480		$	14,533	$	-4	$	―	$	14,529
		Total revenues	$	20,910	$	1,546		$	2,145		$	24,601		$	163		$	-166	$	24,598	Intersegment revenues			38		―			58			96			47			-143		―	Intersegment revenues			33		―			11			44		48		-92		―
	Interest expense		$	986	$	86		$	64		$	1,136		$	417		$	-7	$	1,546		Total revenues	$	16,080	$	1,549		$	2,078		$	19,707		$	60		$	-143	$	19,624		Total revenues	$	10,619	$	1,467		$	2,491		$	14,577	$	44	$	-92	$	14,529
	Depreciation and amortization			2,323		100			250			2,673			135			―		2,808	Interest expense		$	806	$	77		$	63		$	946		$	296		$	―	$	1,242	Interest expense		$	568	$	47		$	87		$	702	$	157	$	―	$	859
	Equity in earnings of unconsolidated affiliates			-1		110			7			116			6			―		122	Depreciation and amortization			1,827		99			228			2,154			135			―		2,289	Depreciation and amortization			1,383		90			230			1,703		103		―		1,806
	Income tax expense (benefit)			1,522		166			-104			1,584			-323			―		1,261	Equity in earnings of unconsolidated affiliates			-5		134			14			143			5			―		148	Equity in earnings of unconsolidated affiliates			―		145			6			151		9		―		160
	Segment income^{(a)(b)(c)(d)(e)(f)(g)}			2,504		408			-3			2,909			-261			―		2,648	Income tax expense (benefit)			942		149			-8			1,083			-378			―		705	Income tax expense (benefit)			674		196			-2			868		-116		―		752
	Add back noncontrolling interest component																			11	Segment income^(a)(b)			1,744		439			87			2,270			-538			―		1,732	Segment income^(a)(b)			1,181		466			134			1,781		-76		―		1,705
	Income from discontinued operations, net of tax																			17	Add back noncontrolling interest component																			14	Add back noncontrolling interest component																	8
	Net income																		$	2,676	Income from discontinued operations, net of tax																			36	Income from discontinued operations, net of tax																	1
	Capital investments expenditures and acquisitions		$	5,049	$	67		$	268		$	5,384		$	223		$	―	$	5,607	Net income																		$	1,782	Net income																$	1,714
	Segment assets			99,884		4,998			6,955			111,837			2,754			188		114,779	Capital investments expenditures and acquisitions		$	4,220	$	551		$	1,038		$	5,809		$	149		$	―	$	5,958	Capital investments expenditures and acquisitions		$	3,717	$	114		$	492		$	4,323	$	141	$	―	$	4,464
																					Segment assets			98,162		5,406			6,992			110,560			3,126			170		113,856	Segment assets			47,977		4,539			6,939			59,455		2,961		110		62,526
	(a)	In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts Regulated Utilities. 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 Regulated Utilities. See Note 4 for additional information about the revised customer rates.																			(a)	Regulated Utilities recorded charges related to Duke Energy Indiana's IGCC project. See Note 4 for additional information about these charges. Regulated Utilities 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 19 for additional information about these expenses.																			(a)	Regulated Utilities recorded charges related to Duke Energy Indiana's IGCC project. See Note 4 for additional information about these charges.
	(c)	In September 2013, Duke Energy Carolinas implemented revised rates approved by the NCUC and the PSCSC. This increase impacts Regulated Utilities. See Note 4 for additional information about the revised customer rates.																			(b)	Other includes after-tax costs to achieve the merger with Progress Energy. See Notes 2 and 25 for additional information about the merger and related costs.																			(b)	Commercial Power recorded charges to write-down the carrying value of certain emission allowances. See Note 11 for additional information about these charges.
	(d)	Regulated Utilities recorded charges related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information about the Crystal River Unit 3 charges.
	(e)	Regulated Utilities recorded an impairment charge related to Duke Energy Progress' Shearon Harris Nuclear Station (Harris) site. Regulated Utilities also recorded an impairment charge related to Duke Energy Florida's proposed nuclear plant in Levy County, Florida (Levy) site. 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. See Notes 2 and 25 for additional information about the merger and related costs.
	(g)	Other includes gain from the sale of Duke Energy's ownership interest in DukeNet. See Note 12 for additional information on the sale of DukeNet.
Schedule Of Revenue And Long-Lived Assets, By Geographical Area	'																				'																				'
	The following table includes information by geographic segment.

	(in millions)		U.S.		Latin America^(a)			Consolidated
	2013
	Consolidated revenues		$	23,053	$	1,545		$	24,598
	Consolidated long-lived assets			78,581		2,781			81,362
	2012
	Consolidated revenues		$	18,078	$	1,546		$	19,624
	Consolidated long-lived assets			79,144		2,467			81,611
	2011
	Consolidated revenues		$	13,062	$	1,467		$	14,529
	Consolidated long-lived assets			45,920		2,612			48,532

	(a)	Change in amounts of long-lived assets in Latin America includes foreign currency translation adjustments on property, plant and equipment and other long-lived asset balances.

Schedule of Net Loss for Other Segment	'																				'																				'

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Duke Energy Carolinas		$	-97	$	-169		$	-46
	Progress Energy			-241		-379			-273
	Duke Energy Progress			-46		-139			-18
	Duke Energy Florida			-24		-58			-16
	Duke Energy Indiana			-16		-27			-12

Duke Energy Ohio [Member]	'																				'																				'
Segment Reporting Information [Line Items]	'																				'																				'
Business Segment Data	'																				'																				'
			Year Ended December 31, 2013																				Year Ended December 31, 2012																				Year Ended December 31, 2011
	(in millions)		Regulated Utilities		Commercial Power		Total Reportable Segments			Other			Eliminations			Total					(in millions)		Regulated Utilities		Commercial Power		Total Reportable Segments			Other			Eliminations			Total					(in millions)		Regulated Utilities		Commercial Power		Total Reportable Segments			Other			Eliminations		Total
	Unaffiliated revenues^(a)		$	1,765	$	1,480	$	3,245		$	―		$	―		$	3,245				Unaffiliated revenues^(a)		$	1,745	$	1,407	$	3,152		$	―		$	―		$	3,152				Unaffiliated revenues^(a)		$	1,474	$	1,707	$	3,181		$	―		$	―	$	3,181
	Intersegment revenues			―		32		32			―			-32			―				Intersegment revenues			1		51		52			―			-52			―				Intersegment revenues			―		4		4			―			-4		―
		Total revenues	$	1,765	$	1,512	$	3,277		$	―		$	-32		$	3,245					Total revenues	$	1,746	$	1,458	$	3,204		$	―		$	-52		$	3,152					Total revenues	$	1,474	$	1,711	$	3,185		$	―		$	-4	$	3,181
	Interest expense		$	74	$	4	$	78		$	―		$	―		$	78				Interest expense		$	61	$	28	$	89		$	―		$	―		$	89				Interest expense		$	68	$	36	$	104		$	―		$	―	$	104
	Depreciation and amortization			200		154		354			―			―			354				Depreciation and amortization			179		159		338			―			―			338				Depreciation and amortization			168		167		335			―			―		335
	Income tax expense (benefit)			91		-14		77			-2			―			75				Income tax expense (benefit)			91		25		116			-18			―			98				Income tax expense (benefit)			98		6		104			-8			―		96
	Segment income/consolidated net income			151		-20		131			-29			―			102				Segment income/consolidated net income			159		50		209			-34			―			175				Segment income/consolidated net income^(b)			133		78		211			-17			―		194
	Capital expenditures			375		58		433			―			―			433				Capital expenditures			427		87		514			―			―			514				Capital expenditures			375		124		499			―			―		499
	Segment assets			6,649		4,170		10,819			99			-155			10,763				Segment assets			6,434		4,175		10,609			117			-166			10,560				Segment assets			6,293		4,740		11,033			259			-353		10,939

	(a)	Duke Energy Ohio earned approximately 37 percent of its consolidated operating revenues from PJM Interconnection, LLC (PJM) in 2013, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.																			(a)	Duke Energy Ohio earned approximately 36 percent of its consolidated operating revenues from PJM in 2012, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.																			(a)	Duke Energy Ohio earned approximately 24 percent of its consolidated operating revenues from PJM in 2011, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.
																																									(b)	Commercial Power recorded charges during the year ended December 31, 2011, to write-down the carrying value of certain emission allowances. See Note 11 for additional information.

Regulatory_Matters_Tables

Regulatory Matters (Tables)	12 Months Ended
Regulatory Matters (Tables)	Dec. 31, 2013																Dec. 31, 2012
Public Utilities, General Disclosures [Line Items]	'																'
Schedule of Regulatory Assets	'																'

			31-Dec-13															31-Dec-12
	(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
	Regulatory Assets																Regulatory Assets
	Accrued pension and OPEB		$	1,723	$	347	$	750	$	269	$	438	$	120	$	219	Accrued pension and OPEB	$	3,306	$	602		1,650	$	769	$	754	$	225	$	325
	Retired generation facilities			1,748		68		1,619		241		1,378		―		61	Retired generation facilities		1,781		―		1,720		128		1,592		―		61
	Debt fair value adjustment			1,338		―		―		―		―		―		―	Debt fair value adjustment		1,472		―		―		―		―		―		―
	Asset retirement obligations			1,608		123		786		389		397		―		―	Asset retirement obligations		1,461		48		713		372		341		―		―
	Net regulatory asset related to income taxes			1,115		555		331		113		218		72		157	Net regulatory asset related to income taxes		1,373		731		401		175		226		82		158
	Hedge costs and other deferrals			450		98		318		165		153		5		29	Hedge costs and other deferrals		710		88		550		240		310		9		63
	Demand side management (DSM)/Energy efficiency (EE)			371		140		152		140		12		79		―	DSM/EE		322		107		121		121		―		94		―
	Vacation accrual			210		82		55		50		―		7		13	Vacation accrual		245		85	$	65		65		―		7		13
	Deferred fuel			94		―		37		6		31		14		43	Deferred fuel		162		―		109		―		109		1		52
	Nuclear deferral			262		40		222		77		145		―		―	Nuclear deferral		142		―		142		―		142		―		―
	Post-in-service carrying costs and deferred operating expenses			459		150		137		19		118		21		151	Post-in-service carrying costs and deferred operating expenses		122		27		―		―		―		19		76
	Gasification services agreement buyout			75		―		―		―		―		―		75	Gasification services agreement buyout		95		―		―		―		―		―		95
	Transmission expansion obligation			70		―		―		―		―		74		―	Transmission expansion obligation		72		―		―		―		―		72		―
	Manufactured gas plant (MGP)			90		―		―		―		―		90		―	MGP		77		―		―		―		―		77		―
	Other			473		219		101		42		60		46		87	Other		401		260		77		52		26		39		93
	Total regulatory assets			10,086		1,822		4,508		1,511		2,950		528		835	Total regulatory assets		11,741		1,948		5,548		1,922		3,500		625		936
	Less: current portion			895		295		353		127		221		57		118	Less: current portion		737		221		256		77		179		46		126
	Total non-current regulatory assets		$	9,191	$	1,527	$	4,155	$	1,384	$	2,729	$	471	$	717	Total non-current regulatory assets	$	11,004	$	1,727	$	5,292	$	1,845	$	3,321	$	579	$	810

Schedule Of Regulatory Liabilities	'																'

			31-Dec-13															31-Dec-12
	(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
	Regulatory Liabilities																Regulatory Liabilities
	Costs of removal		$	5,308	$	2,423	$	2,008	$	1,637	$	371	$	241	$	645	Costs of removal	$	4,827	$	1,928	$	2,048	$	1,503	$	401	$	236	$	624
	Amounts to be refunded to customers			151		―		120		―		120		―		31	Amounts to be refunded to customers		290		―		259		―		259		―		31
	Storm reserve			145		20		125		―		125		―		―	Storm reserve		125		―		125		―		125		―		―
	Accrued pension and OPEB			138		―		―		―		―		21		77	Accrued pension and OPEB		103		―		―		―		―		18		68
	Deferred fuel			177		45		132		―		132		―		―	Deferred fuel		55		45		10		10		―		―		―
	Other			346		153		114		99		14		27		45	Other		340		207		55		35		20		39		29
	Total regulatory liabilities			6,265		2,641		2,499		1,736		762		289		798	Total regulatory liabilities		5,740		2,180		2,497		1,548		805		293		752
	Less: current portion			316		65		207		63		144		27		16	Less: current portion		156		78		28		10		18		39		11
	Total non-current regulatory liabilities		$	5,949	$	2,576	$	2,292	$	1,673	$	618	$	262	$	782	Total non-current regulatory liabilities	$	5,584	$	2,102	$	2,469	$	1,538	$	787	$	254	$	741


Schedule of Potential Plant Retirements	'																'

			31-Dec-13
				Duke Energy	Duke Energy Carolinas^(b)		Progress Energy^(c)		Duke Energy Florida^(c)		Duke Energy Ohio^(d)		Duke Energy Indiana^(e)
	Capacity (in MW)			2,447		200		873		873		706		668
	Remaining net book value (in millions)^(a)		$	260	$	14	$	113	$	113	$	10	$	123

	(a)	Included in Property, plant and equipment, net as of December 31, 2013, on the Consolidated Balance Sheets.
	(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 Crystal River Units 1 and 2.
	(d)	Includes Beckjord Units 4 through 6 and Miami Fort Unit 6. 150 MW Beckjord Station Unit 4 was retired on February 17, 2014. Beckjord units have no remaining book value.
	(e)	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	'																'

			31-Dec-13
								Remaining Amount to be Refunded
	(in millions)		Total		Refunded to date		2014		2015		2016
	2012 Settlement refund^(a)		$	288	$	129	$	139	$	10	$	10
	Retirement decision refund			100		-		-		40		60
	NEIL proceeds			490		326		164		-		-
	Total customer refunds			878		455		303		50		70
	Accelerated regulatory asset recovery			-130		-		-37		-37		-56
	Net customer refunds		$	748	$	455	$	266	$	13	$	14

	(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 December 31, 2013^(a)
	Duke Energy Ohio		$	97	$	2	$	-4	$	95

	(a)	As of December 31, 2013, $74 million is recorded as a Regulatory asset on Duke Energy Ohio's Consolidated Balance Sheets.

Commitments_and_Contingencies_

Commitments and Contingencies (Table)	12 Months Ended
Commitments and Contingencies (Table)	Dec. 31, 2013
Valuation and Qualifying Accounts Disclosure [Line Items]	'
Accrual For Environmental Loss Contingencies	'

	(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, 2010		$	88		$	13		$	35	$	12	$	23	$	50	$	11
	Provisions / adjustments			6			―			10		1		9		5		1
	Cash reductions			-33			-1			-22		-2		-20		-27		-3
	Balance at December 31, 2011			61			12			23		11		12		28		9
	Provisions / adjustments			39			1			19		5		14		5		3
	Cash reductions			-25			-1			-9		-2		-7		-18		-4
	Balance at December 31, 2012			75			12			33		14		19		15		8
	Provisions / adjustments			26			―			4		-1		5		20		1
	Cash reductions			-22			-1			-10		-5		-5		-8		-2
	Balance at December 31, 2013		$	79		$	11		$	27	$	8	$	19	$	27	$	7

Schedule of Additional Possible Losses in Excess of Recorded Environmental Reserves	'
	Additional losses in excess of recorded reserves that could be incurred for the stages of investigation, remediation and monitoring for environmental sites that have been evaluated at this time are presented in the table below.

	(in millions)
	Duke Energy		$	74
	Duke Energy Carolinas			29
	Progress Energy			5
	Duke Energy Progress			2
	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)
	Duke Energy		$	525		to	$	625
	Duke Energy Carolinas			40		to		50
	Progress Energy			25		to		40
	Duke Energy Progress			10		to		15
	Duke Energy Florida			15		to		25
	Duke Energy Ohio			35		to		50
	Duke Energy Indiana			425		to		485

Schedule of Litigation Reserves and Related Insurance Recoveries	'

			December 31,
	(in millions)		2013			2012
	Reserves for Legal and Other Matters^(a)
	Duke Energy^(b)		$	824		$	846
	Duke Energy Carolinas^(b)			616			751
	Progress Energy			78			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)	Classified in the respective 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)	Classified in the respective Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
	(e)	Relates to recoveries associated with asbestos-related injuries and damages claims.

Schedule of Rent Expense	'

			Years Ended December 31,
	(in millions)		2013		2012			2011
	Duke Energy		$	321		$	232		$	104
	Duke Energy Carolinas			39			38			43
	Progress Energy			225			232			104
	Duke Energy Progress			153			164			88
	Duke Energy Florida			72			68			15
	Duke Energy Ohio			14			14			19
	Duke Energy Indiana			22			20			24

Schedule of Future Minimum Rental Payments for Operating Leases	'
	The following table presents future minimum lease payments under operating leases, which at inception had a non-cancelable term of more than one year.

			31-Dec-13
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	2014		$	175		$	34		$	93	$	55	$	39	$	12	$	18
	2015			159			29			89		51		39		11		15
	2016			147			24			90		51		39		8		12
	2017			137			20			89		50		39		7		9
	2018			117			15			78		40		38		5		7
	Thereafter			1,034			67			773		459		314		18		8
	Total		$	1,769		$	189		$	1,212	$	706	$	508	$	61	$	69

Schedule of Future Minimum Lease Payments for Capital Leases	'
	The following table presents future minimum lease payments under capital leases.

			31-Dec-13
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	2014		$	171		$	6		$	47	$	20	$	26	$	9	$	5
	2015			167			6			47		20		27		7		4
	2016			169			6			47		21		26		6		4
	2017			166			6			46		21		26		3		2
	2018			176			6			45		21		25		3		2
	Thereafter			1,453			25			475		261		213		2		28
	Minimum annual payments			2,302			55			707		364		343		30		45
	Less amount representing interest			-786			-27			-454		-275		-179		-3		-30
	Total		$	1,516		$	28		$	253	$	89	$	164	$	27	$	15

Duke Energy Progress [Member]	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'
Schedule of Purchase Obligations	'
							Minimum Purchase Amount at December 31, 2013
	(in millions)			Contract Expiration		2014			2015		2016		2017		2018		Thereafter		Total
	Duke Energy Progress^(a)			2019-2022		$	36			36	$	36	$	37	$	37	$	69	$	251
	Duke Energy Florida^(b)			2014-2025			288			295		295		288		303		2,139		3,608
	Duke Energy Ohio^(c)			2014-2015			250			97		―		―		―		―		347

	(a)	Contracts represent 100 percent of net plant output.
	(b)	Contracts represent between 2 percent and 100 percent of net plant output.
	(c)	Contracts represent between 1 percent and 24 percent of net plant output.

Duke Energy Florida [Member]	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'
Schedule of Purchase Obligations	'
							Minimum Purchase Amount at December 31, 2013
	(in millions)			Contract Expiration		2014			2015		2016		2017		2018		Thereafter		Total
	Duke Energy Progress^(a)			2019-2022		$	36			36	$	36	$	37	$	37	$	69	$	251
	Duke Energy Florida^(b)			2014-2025			288			295		295		288		303		2,139		3,608
	Duke Energy Ohio^(c)			2014-2015			250			97		―		―		―		―		347

	(a)	Contracts represent 100 percent of net plant output.
	(b)	Contracts represent between 2 percent and 100 percent of net plant output.
	(c)	Contracts represent between 1 percent and 24 percent of net plant output.

Duke Energy Ohio [Member]	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'
Schedule of Purchase Obligations	'
							Minimum Purchase Amount at December 31, 2013
	(in millions)			Contract Expiration		2014			2015		2016		2017		2018		Thereafter		Total
	Duke Energy Progress^(a)			2019-2022		$	36			36	$	36	$	37	$	37	$	69	$	251
	Duke Energy Florida^(b)			2014-2025			288			295		295		288		303		2,139		3,608
	Duke Energy Ohio^(c)			2014-2015			250			97		―		―		―		―		347

	(a)	Contracts represent 100 percent of net plant output.
	(b)	Contracts represent between 2 percent and 100 percent of net plant output.
	(c)	Contracts represent between 1 percent and 24 percent of net plant output.

Debt_and_Credit_Facilities_Tab

Debt and Credit Facilities (Tables)	12 Months Ended
Debt and Credit Facilities (Tables)	Dec. 31, 2013																						Dec. 31, 2012
Debt Instrument [Line Items]	'																						'
Schedule of Debt	'																						'

			31-Dec-13																						31-Dec-12
	(in millions)		Weighted Average Interest Rate		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana						(in millions)		Weighted Average Interest Rate			Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Unsecured debt, maturing 2014 - 2073		5.18	%	$	13,550	$	1,157	$	4,150	$	―	$	150	$	805	$	744					Unsecured debt, maturing 2013 - 2039		5.44	%		$	12,722	$	1,159	$	4,150	$	―	$	150	$	805	$	1,146
	Secured debt, maturing 2014 - 2037		2.69	%		2,559		400		305		305		―		―		―					Secured debt, maturing 2013 - 2037		3.08	%			1,873		300		5		5		―		―		―
	First mortgage bonds, maturing 2015 - 2043^(a)		4.9	%		17,831		6,161		8,450		4,125		4,325		900		2,319					First mortgage bonds, maturing 2013 - 2042^(a)		5	%			17,856		6,562		8,775		4,025		4,750		700		1,819
	Capital leases, maturing 2014 - 2051^(b)		5.23	%		1,516		30		327		148		179		27		20					Capital leases, maturing 2013 - 2051^(b)		5.19	%			1,689		32		339		150		189		35		23
	Other debt, maturing 2027		4.77	%		8		―		―		―		―		8		―					Junior subordinated debt, maturing 2039		7.1	%			309		―		309		―		―		―		―
	Tax-exempt bonds, maturing 2014 - 2041^(c)		1.28	%		2,356		395		910		669		241		479		573					Other debt, maturing 2027		4.77	%			8		―		―		―		―		8		―
	Notes payable and commercial paper^(d)		1.02	%		1,289		―		―		―		―		―		―					Tax exempt bonds, maturing 2014 - 2041^(c)		1.39	%			2,357		395		910		669		241		479		573
	Money pool/intercompany borrowings					―		300		1,213		462		181		43		150					Notes payable and commercial paper^(d)		0.83	%			1,507		―		―		―		―		―		―
	Fair value hedge carrying value adjustment					9		9		―		―		―		―		―					Money pool/intercompany borrowings						―		300		455		364		―		245		231
	Unamortized debt discount and premium, net^(e)					1,977		-16		-27		-12		-9		-31		-10					Fair value hedge carrying value adjustment						12		10		―		―		―		2		―
	Total debt					41,095		8,436		15,328		5,697		5,067		2,231		3,796					Unamortized debt discount and premium, net^(e)						2,185		-17		-60		-9		-10		-32		-9
	Short-term notes payable and commercial paper					-839		―		―		―		―		―		―					Total debt						40,518		8,741		14,883		5,204		5,320		2,242		3,783
	Short-term money pool borrowings					―		―		-1,213		-462		-181		-43		―					Short-term notes payable and commercial paper						-1,057		―		―		―		―		―		―
	Current maturities of long-term debt					-2,104		-47		-485		-174		-11		-47		-5					Short-term money pool borrowings						―		―		-455		-364		―		-245		-81
	Total long-term debt^(f)				$	38,152	$	8,389	$	13,630	$	5,061	$	4,875	$	2,141	$	3,791					Current maturities of long-term debt						-3,110		-406		-843		-407		-435		-261		-405
																							Total long-term debt^(f)					$	36,351	$	8,335	$	13,585	$	4,433	$	4,885	$	1,736	$	3,297
	(a)	Substantially all electric utility fixed assets are mortgaged under mortgage bond indentures.
	(b)	Duke Energy includes $144 million and $838 million of capital lease purchase accounting adjustments related to Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as leases in their financial statements because of grandfathering provisions in GAAP.																					(a)	Substantially all electric utility fixed assets are mortgaged under mortgage bond indentures.
	(c)	Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.																					(b)	Duke Energy includes $158 million and $907 million of capital lease purchase accounting adjustments for Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as leases on their financial statements because of grandfathering provisions in GAAP.
	(d)	Includes $450 million that was classified as Long-term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energy’s ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 49 days.																					(c)	Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.
	(e)	Duke Energy includes $2,067 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.																					(d)	Includes $450 million that was classified as Long-term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energy’s ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 18 days.
	(f)	Includes $1,966 million for Duke Energy, $400 million for Duke Energy Carolinas and $300 million for Progress Energy and Duke Energy Progress related to consolidated VIEs.																					(e)	Duke Energy includes $2,311 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.
																							(f)	Includes $852 million for Duke Energy and $300 million for Duke Energy Carolinas related to consolidated VIEs.

Schedule Of Significant Debt Issuances	'																						'

							Year Ended December 31, 2013																						Year Ended December 31, 2012
	Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)			Duke Energy Progress				Duke Energy Ohio		Duke Energy Indiana			Duke Energy				Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)		Duke Energy Carolinas		Progress Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy Indiana			Duke Energy
	Unsecured Debt																						Unsecured Debt
	January 2013^(a)		Jan-73	5.125	%		$	500		$	―		$	―		$	―		$	500			March 2012^(a)		Apr-22	3.15	%		$	―	$	―	$	450	$	―	$	―	$	―	$	450
	June 2013^(b)		Jun-18	2.1	%			500			―			―			―			500			August 2012^(b)		Aug-17	1.63	%			700		―		―		―		―		―		700
	August 2013^(c)(d)		Aug-23	11	%			―			―			―			―			220			August 2012^(b)		Aug-22	3.05	%			500		―		―		―		―		―		500
	October 2013^(e)		Oct-23	3.95	%			400			―			―			―			400			Secured Debt
	Secured Debt																						April 2012^(c)		Sep-24	2.64	%			330		―		―		―		―		―		330
	February 2013^(f)(g)		Dec-30	2.043	%			―			―			―			―			203			December 2012^(d)		Mar-13	2.77	%			203		―		―		―		―		―		203
	February 2013^(f)		Jun-37	4.74	%			―			―			―			―			220			December 2012^(d)		Mar-13	4.74	%			220		―		―		―		―		―		220
	April 2013^(h)		Apr-26	5.456	%			―			―			―			―			230			December 2012^(e)		Jun-13	1.01	%			190		―		―		―		―		―		190
	December 2013⁽ⁱ⁾		Dec-16	0.852	%			―			300			―			―			300			December 2012^(e)		Dec-25	1.56	%			200		―		―		―		―		―		200
	First Mortgage Bonds																						First Mortgage Bonds
	March 2013^(j)		Mar-43	4.1	%			―			500			―			―			500			March 2012^(f)		Mar-42	4.2	%			―		―		―		―		―		250		250
	July 2013^(k)		Jul-43	4.9	%			―			―			―			350			350			May 2012^(g)		May-22	2.8	%			―		―		―		500		―		―		500
	July 2013^(k)(l)		Jul-16	0.619	%			―			―			―			150			150			May 2012^(g)		May-42	4.1	%			―		―		―		500		―		―		500
	September 2013^(m)		Sep-23	3.8	%			―			―			300			―			300			September 2012^(h)		Sep-42	4	%			―		650		―		―		―		―		650
	September 2013^(m)(n)		Mar-15	0.4	%			―			―			150			―			150			November 2012⁽ⁱ⁾		Nov-15	0.65	%			―		―		―		―		250		―		250
	Total Issuances						$	1,400		$	800		$	450		$	500		$	4,023			November 2012⁽ⁱ⁾		Nov-42	3.85	%			―		―		―		―		400		―		400
																							Total Issuances						$	2,343	$	650	$	450	$	1,000	$	650	$	250	$	5,343
	(a)	Callable after January 2018 at par. Proceeds were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS) and to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 17 for additional information about the QUIPS.
	(b)	Proceeds were used to repay $250 million of current maturities and for general corporate purposes, including the repayment of outstanding commercial paper.																					(a)	Proceeds were used to repay current maturities of $450 million.
	(c)	Proceeds 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.																					(b)	Proceeds were used to repay current maturities of $500 million, as well as for general corporate purposes, including the repayment of commercial paper.
	(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.																					(c)	Proceeds were used to reimburse construction costs for DS Cornerstone, LLC joint venture wind projects. Debt was subsequently deconsolidated upon execution of a joint venture. See Note 17 for further details.
	(e)	Proceeds were used to repay commercial paper as well as for general corporate purposes.																					(d)	Proceeds were used to fund the existing Los Vientos wind power portfolio.
	(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.																					(e)	Debt issuances were executed in connection with the acquisition of Ibener. Both loans were collateralized with cash deposits equal to 101 percent of the loan amounts. See Note 2 for further details.
	(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.																					(f)	Proceeds were used to repay a portion of outstanding short-term debt.
	(h)	Represents 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.																					(g)	Proceeds were used to repay current maturities of $500 million, a portion of outstanding commercial paper and notes payable to affiliated companies.
	(i)	Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Progress; the proceeds were used to repay short-term debt. See Note 17 for further details.																					(h)	Proceeds were used to repay current maturities of $420 million, as well as for general corporate purposes, including the funding of capital expenditures.
	(j)	Proceeds were used to repay notes payable to affiliated companies as well as for general corporate purposes.																					(i)	Proceeds will be used to repay current maturities of $425 million, as well as for general corporate purposes.
	(k)	Proceeds 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 credit spread of 35 basis points.
	(m)	Proceeds 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.																											Year Ended December 31, 2012
	(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 Carolinas		Progress Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy Indiana			Duke Energy
																							Unsecured Debt
																							March 2012^(a)		Apr-22	3.15	%		$	―	$	―	$	450	$	―	$	―	$	―	$	450
							Year Ended December 31, 2013																August 2012^(b)		Aug-17	1.63	%			700		―		―		―		―		―		700
	Issuance Date		Maturity Date	Interest Rate			Duke Energy (Parent)			Duke Energy Progress				Duke Energy Ohio		Duke Energy Indiana			Duke Energy				August 2012^(b)		Aug-22	3.05	%			500		―		―		―		―		―		500
	Unsecured Debt																						Secured Debt
	January 2013^(a)		Jan-73	5.125	%		$	500		$	―		$	―		$	―		$	500			April 2012^(c)		Sep-24	2.64	%			330		―		―		―		―		―		330
	June 2013^(b)		Jun-18	2.1	%			500			―			―			―			500			December 2012^(d)		Mar-13	2.77	%			203		―		―		―		―		―		203
	August 2013^(c)(d)		Aug-23	11	%			―			―			―			―			220			December 2012^(d)		Mar-13	4.74	%			220		―		―		―		―		―		220
	October 2013^(e)		Oct-23	3.95	%			400			―			―			―			400			December 2012^(e)		Jun-13	1.01	%			190		―		―		―		―		―		190
	Secured Debt																						December 2012^(e)		Dec-25	1.56	%			200		―		―		―		―		―		200
	February 2013^(f)(g)		Dec-30	2.043	%			―			―			―			―			203			First Mortgage Bonds
	February 2013^(f)		Jun-37	4.74	%			―			―			―			―			220			March 2012^(f)		Mar-42	4.2	%			―		―		―		―		―		250		250
	April 2013^(h)		Apr-26	5.456	%			―			―			―			―			230			May 2012^(g)		May-22	2.8	%			―		―		―		500		―		―		500
	December 2013⁽ⁱ⁾		Dec-16	0.852	%			―			300			―			―			300			May 2012^(g)		May-42	4.1	%			―		―		―		500		―		―		500
	First Mortgage Bonds																						September 2012^(h)		Sep-42	4	%			―		650		―		―		―		―		650
	March 2013^(j)		Mar-43	4.1	%			―			500			―			―			500			November 2012⁽ⁱ⁾		Nov-15	0.65	%			―		―		―		―		250		―		250
	July 2013^(k)		Jul-43	4.9	%			―			―			―			350			350			November 2012⁽ⁱ⁾		Nov-42	3.85	%			―		―		―		―		400		―		400
	July 2013^(k)(l)		Jul-16	0.619	%			―			―			―			150			150			Total Issuances						$	2,343	$	650	$	450	$	1,000	$	650	$	250	$	5,343
	September 2013^(m)		Sep-23	3.8	%			―			―			300			―			300
	September 2013^(m)(n)		Mar-15	0.4	%			―			―			150			―			150			(a)	Proceeds were used to repay current maturities of $450 million.
	Total Issuances						$	1,400		$	800		$	450		$	500		$	4,023			(b)	Proceeds were used to repay current maturities of $500 million, as well as for general corporate purposes, including the repayment of commercial paper.
																							(c)	Proceeds were used to reimburse construction costs for DS Cornerstone, LLC joint venture wind projects. Debt was subsequently deconsolidated upon execution of a joint venture. See Note 17 for further details.
	(a)	Callable after January 2018 at par. Proceeds were used to redeem the $300 million 7.10% Cumulative Quarterly Income Preferred Securities (QUIPS) and to repay a portion of outstanding commercial paper and for general corporate purposes. See Note 17 for additional information about the QUIPS.																					(d)	Proceeds were used to fund the existing Los Vientos wind power portfolio.
	(b)	Proceeds were used to repay $250 million of current maturities and for general corporate purposes, including the repayment of outstanding commercial paper.																					(e)	Debt issuances were executed in connection with the acquisition of Ibener. Both loans were collateralized with cash deposits equal to 101 percent of the loan amounts. See Note 2 for further details.
	(c)	Proceeds 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.																					(f)	Proceeds were used to repay a portion of outstanding short-term debt.
	(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.																					(g)	Proceeds were used to repay current maturities of $500 million, a portion of outstanding commercial paper and notes payable to affiliated companies.
	(e)	Proceeds were used to repay commercial paper as well as for general corporate purposes.																					(h)	Proceeds were used to repay current maturities of $420 million, as well as for general corporate purposes, including the funding of capital expenditures.
	(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.																					(i)	Proceeds will be used to repay current maturities of $425 million, as well as for general corporate purposes.
(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 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)	Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Progress; the proceeds were used to repay short-term debt. See Note 17 for further details.
(j)	Proceeds were used to repay notes payable to affiliated companies as well as for general corporate purposes.
(k)	Proceeds 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 credit spread of 35 basis points.
(m)	Proceeds 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		31-Dec-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
	Tax-exempt Bonds
	Duke Energy Progress		Jan-14	0.105	%		167
	Other						387
	Current maturities of long-term debt					$	2,104


	(in millions)		Maturity Date	Interest Rate		31-Dec-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
	Tax-exempt Bonds
	Duke Energy Progress		Jan-14	0.105	%		167
	Other						387
	Current maturities of long-term debt					$	2,104

Schedule of Maturities of Long-term Debt	'																						'

			31-Dec-13
	(in millions)		Duke Energy^(a)			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	2014		$	2,104		$	47		$	485		$	174		$	11		$	47		$	5
	2015			2,634			507			1,264			702			562			157			5
	2016			2,975			756			614			302			12			56			480
	2017			1,342			116			265			3			262			2			3
	2018			3,235			1,505			603			59			544			3			153
	Thereafter			25,899			5,505			10,884			3,995			3,495			1,923			3,150
	Total long-term debt, including current maturities		$	38,189		$	8,436		$	14,115		$	5,235		$	4,886		$	2,188		$	3,796

	(a)	Excludes $2,067 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.

Schedule Of Line Of Credit Facilities	'																						'

					31-Dec-13
	(in millions)				Duke Energy		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Facility size^(a)			$	6,000	$	2,250		$	1,000		$	750		$	650		$	650		$	700
	Reduction to backstop issuances
		Notes payable and commercial paper^(b)			-450		―			-300			―			―			―			-150
		Outstanding letters of credit			-62		-55			-4			-2			-1			―			―
		Tax-exempt bonds			-240		―			-75			―			―			-84			-81
	Available capacity			$	5,248	$	2,195		$	621		$	748		$	649		$	566		$	469

	(a)	Represents the sublimit of each borrower at December 31, 2013. The Duke Energy Ohio sublimit includes $100 million for Duke Energy Kentucky.
	(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 Carolinas' and Duke Energy Indiana's Condensed Consolidated Balance Sheets.


					31-Dec-13
	(in millions)				Duke Energy		Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
	Facility size^(a)			$	6,000	$	2,250		$	1,000		$	750		$	650		$	650		$	700
	Reduction to backstop issuances
		Notes payable and commercial paper^(b)			-450		―			-300			―			―			―			-150
		Outstanding letters of credit			-62		-55			-4			-2			-1			―			―
		Tax-exempt bonds			-240		―			-75			―			―			-84			-81
	Available capacity			$	5,248	$	2,195		$	621		$	748		$	649		$	566		$	469

	(a)	Represents the sublimit of each borrower at December 31, 2013. The Duke Energy Ohio sublimit includes $100 million for Duke Energy Kentucky.
	(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 Carolinas' and Duke Energy Indiana's Condensed Consolidated Balance Sheets.

Schedule Of Short Term Obligations Classifed As Long Term	'																						'

			31-Dec-13																						31-Dec-12
	(in millions)		Duke Energy			Duke Energy Carolinas			Duke Energy Ohio			Duke Energy Indiana											(in millions)		Duke Energy			Duke Energy Carolinas			Duke Energy Ohio			Duke Energy Indiana
	Tax-exempt bonds		$	471		$	75		$	111		$	285										Tax exempt bonds		$	471		$	75		$	111		$	285
	Notes payable and commercial paper			450			300			―			150										Notes payable and commercial paper			450			300			―			150
	Secured debt^(a)			200			―			―			―										Secured debt^(a)			200			―			―			―
	Total		$	1,121		$	375		$	111		$	435										DERF^(b)			300			300
																							Total		$	1,421		$	675		$	111		$	435

																							(a)	Instrument has a term of less than one year with the right to extend the maturity date for additional one-year periods with a final maturity date no later than December 2026.
																							(a)	Duke Energy Receivables Finance Company, LLC (DERF) is a wholly owned limited liability company of Duke Energy Carolinas. See Note 17 for further information.

Guarantees_and_Indemnification1

Guarantees and Indemnifications (Tables)	12 Months Ended
Guarantees and Indemnifications (Tables)	Dec. 31, 2013
Guarantor Obligations [Line Items]	'
Schedule of Guarantor Obligations	'

		December 31,
		2013			2012
	Duke Energy		$	24		$	41
	Progress Energy			9			25
	Duke Energy Florida			3			17

Recovered_Sheet1

Joint Ownership of Generating and Transmission Facilities (Tables)	12 Months Ended
	Dec. 31, 2013
Jointly Owned Utility Plant Interests [Line Items]	'
Schedule Joint Ownership of Generating and Transmission Facilities	'

			31-Dec-13
			Ownership Share		Property, Plant and Equipment		Accumulated Depreciation		Construction Work in Progress
	Duke Energy Carolinas
		Catawba Nuclear Station (Units 1 and 2)^(a)(b)	19.25	%	$	887	$	498	$	―
	Duke Energy Progress
		Mayo Station^(a)(c)	83.83			856		303		104
		Shearon Harris Nuclear Station^(a)(c)	83.83			3,620		2,018		67
		Brunswick Nuclear Station^(a)(c)	81.67			1,921		1,005		176
		Roxboro Station (Unit 4)^(a)(c)	87.06			754		473		13
	Duke Energy Florida
		Crystal River Nuclear Station (Unit 3)^(a)(d)	91.78			―		―		―
		Intercession City Station (Unit P11)^(a)(e)	66.67			25		13		―
	Duke Energy Ohio
		Miami Fort Station (Units 7 and 8)^(f)(g)	64			624		232		1
		W.C. Beckjord Station (Unit 6)^(f)(h)	37.5			―		―		―
		J.M. Stuart Station^(f)(h)(i)	39			823		281		16
		Conesville Station (Unit 4)^(f)(h)(i)	40			318		49		3
		W.M. Zimmer Station^(f)(h)	46.5			1,358		574		4
		Killen Station^(f)(g)(i)	33			308		139		2
		East Bend Station^(a)(g)	69			447		240		13
		Transmission facilities^(a)(h)	Various			96		49		―
	Duke Energy Indiana
		Gibson Station (Unit 5)^(a)(j)	50.05			308		160		2
		Vermillion^(a)(k)	62.5			154		61		―
		Transmission and local facilities^(a)(j)	Various			3,726		1,582		―
	International Energy
		Brazil - Canoas I and II^(l)	47.2			266		83		―

	(a)	Included in Regulated Utilities segment.
	(b)	Co-owned with North Carolina Municipal Power Agency Number 1, NCEMC and Piedmont Municipal Power Agency.
	(c)	Co-owned with North Carolina Eastern Municipal Power Agency.
	(d)	All costs associated with Crystal River Unit 3 are included within Regulatory assets on the Consolidated Balance Sheets of Duke Energy, Progress Energy and Duke Energy Florida. See Note 4 for additional information. Co-owned with Seminole Electric Cooperative, Inc., City of Ocala, Orlando Utilities Commission, City of Gainesville, City of Leesburg, Kissimmee Utility Authority, Utilities Commission of the City of New Smyrna Beach, City of Alachua and City of Bushnell.
	(e)	Co-owned with Georgia Power Company. Georgia Power Company has exclusive rights to the output of the unit during the months of June through September.
	(f)	Included in Commercial Power segment.
	(g)	Co-owned with The Dayton Power and Light Company.
	(h)	Co-owned with The Dayton Power and Light Company and Ohio Power Company.
	(i)	Station is not operated by Duke Energy Ohio.
	(j)	Co-owned with WVPA and Indiana Municipal Power Agency.
	(k)	Co-owned with WVPA.
	(l)	Included in International Energy segment. Co-owned with Companhia Brasileira de Aluminio.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	Dec. 31, 2013
Asset Retirement Obligation [Line Items]	'
Schedule of Asset Retirement Obligations	'

	(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		$	1,936	$	1,846	$	1,265	$	896	$	369	$	27	$	43
	Acquisitions^(a)			3,062		—		—		—		—		—		—
	Accretion expense^(b)			173		118		86		64		22		1		1
	Liabilities settled			-15		-3		-2		-2		—		—		-10
	Revisions in estimates of cash flows^(c)			-4		-2		234		—		234		—		-1
	Liabilities incurred in the current year^(d)			24		—		837		698		139		—		4
	Balance at December 31, 2012^(e)			5,176		1,959		2,420		1,656		764		28		37
	Acquisitions			4		—		—		—		—		—		—
	Accretion expense^(b)			239		122		113		80		33		2		—
	Liabilities settled			-12		—		-12		—		-12		—		—
	Revisions in estimates of cash flows^(f)			-449		-487		49		1		48		-2		-7
	Balance at December 31, 2013^(e)		$	4,958	$	1,594	$	2,570	$	1,737	$	833	$	28	$	30

	(a)	Represents asset retirement obligations resulting from the merger with Progress Energy. See Note 2 for additional information.
	(b)	Substantially all accretion expense for the years ended December 31, 2013 and 2012 relates to Duke Energy’s regulated electric operations and has been deferred in accordance with regulatory accounting treatment.
	(c)	For Progress Energy and Duke Energy Florida, the amounts relate to the retirement of Crystal River Unit 3.
	(d)	For Progress Energy, Duke Energy Progress and Duke Energy Florida, amounts primarily relate to spent nuclear fuel disposal recorded in the third quarter of 2012 to conform to Duke Energy's assumptions for nuclear asset retirement obligations.
	(e)	Balances at December 31, 2013 and 2012, include $8 million and $7 million, respectively, reported in Other current liabilities on the Consolidated Balance Sheets at Duke Energy, Progress Energy and Duke Energy Progress.
	(f)	Amounts for Duke Energy, Duke Energy Carolinas and Duke Energy Florida primarily relate to the site-specific nuclear decommissioning cost studies completed in 2013.


Duke Energy Carolinas [Member]	'
Asset Retirement Obligation [Line Items]	'
Summary of Nuclear Decommissioning Trust Fund Requirements	'

	(in millions)		Annual Funding Requirement		Decommissioning Costs^(a)(b)		Year of Cost Study
	Duke Energy Carolinas		$	21	$	3,420	2013
	Duke Energy Progress			14		3,000	2009
	Duke Energy Florida			―		1,083	2013

	(a)	Represents cost per the most recent site-specific nuclear decommissioning cost studies, including costs to decommission plant components not subject to radioactive contamination.
	(b)	Includes the Duke Energy Registrants' ownership interest in jointly owned reactors. Other joint owners are responsible for decommissioning costs related to their interest in the reactors.

Schedule of Nuclear Operating Licenses Expiration	'

	Unit			Year of Expiration
	Duke Energy Carolinas
	Catawba Unit 1			2043
	Catawba Unit 2			2043
	McGuire Unit 1			2041
	McGuire Unit 2			2043
	Oconee Unit 1			2033
	Oconee Unit 2			2033
	Oconee Unit 3			2034
	Duke Energy Progress
	Brunswick Unit 1			2036
	Brunswick Unit 2			2034
	Harris			2046
	Robinson			2030
	Duke Energy Florida
	Crystal River Unit 3^(a)			2016

	(a)	Duke Energy Florida has requested the NRC terminate the Crystal River Unit 3 operating license as a result of the retirement of the unit.

Duke Energy Progress [Member]	'
Asset Retirement Obligation [Line Items]	'
Summary of Nuclear Decommissioning Trust Fund Requirements	'

	(in millions)		Annual Funding Requirement		Decommissioning Costs^(a)(b)		Year of Cost Study
	Duke Energy Carolinas		$	21	$	3,420	2013
	Duke Energy Progress			14		3,000	2009
	Duke Energy Florida			―		1,083	2013

	(a)	Represents cost per the most recent site-specific nuclear decommissioning cost studies, including costs to decommission plant components not subject to radioactive contamination.
	(b)	Includes the Duke Energy Registrants' ownership interest in jointly owned reactors. Other joint owners are responsible for decommissioning costs related to their interest in the reactors.

Schedule of Nuclear Operating Licenses Expiration	'

	Unit			Year of Expiration
	Duke Energy Carolinas
	Catawba Unit 1			2043
	Catawba Unit 2			2043
	McGuire Unit 1			2041
	McGuire Unit 2			2043
	Oconee Unit 1			2033
	Oconee Unit 2			2033
	Oconee Unit 3			2034
	Duke Energy Progress
	Brunswick Unit 1			2036
	Brunswick Unit 2			2034
	Harris			2046
	Robinson			2030
	Duke Energy Florida
	Crystal River Unit 3^(a)			2016

	(a)	Duke Energy Florida has requested the NRC terminate the Crystal River Unit 3 operating license as a result of the retirement of the unit.

Duke Energy Florida [Member]	'
Asset Retirement Obligation [Line Items]	'
Summary of Nuclear Decommissioning Trust Fund Requirements	'

	(in millions)		Annual Funding Requirement		Decommissioning Costs^(a)(b)		Year of Cost Study
	Duke Energy Carolinas		$	21	$	3,420	2013
	Duke Energy Progress			14		3,000	2009
	Duke Energy Florida			―		1,083	2013

	(a)	Represents cost per the most recent site-specific nuclear decommissioning cost studies, including costs to decommission plant components not subject to radioactive contamination.
	(b)	Includes the Duke Energy Registrants' ownership interest in jointly owned reactors. Other joint owners are responsible for decommissioning costs related to their interest in the reactors.

Schedule of Nuclear Operating Licenses Expiration	'

	Unit			Year of Expiration
	Duke Energy Carolinas
	Catawba Unit 1			2043
	Catawba Unit 2			2043
	McGuire Unit 1			2041
	McGuire Unit 2			2043
	Oconee Unit 1			2033
	Oconee Unit 2			2033
	Oconee Unit 3			2034
	Duke Energy Progress
	Brunswick Unit 1			2036
	Brunswick Unit 2			2034
	Harris			2046
	Robinson			2030
	Duke Energy Florida
	Crystal River Unit 3^(a)			2016

	(a)	Duke Energy Florida has requested the NRC terminate the Crystal River Unit 3 operating license as a result of the retirement of the unit.

Property_Plant_Equipment_Table

Property, Plant & Equipment (Tables)	12 Months Ended
Property, Plant & Equipment (Tables)	Dec. 31, 2013																				Dec. 31, 2012
Public Utility, Property, Plant and Equipment [Line Items]	'																				'
Schedule Of Property, Plant And Equipment	'																				'

			Years Ended December 31,																							31-Dec-12
			2013			2012			2011												(in millions)		Estimated Useful Life (Years)				Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Duke Energy		2.8	%		2.9	%		3.2	%											Land					$	1,368	$	378	$	618	$	380	$	239	$	136	$	90
	Duke Energy Carolinas		2.8	%		2.8	%		2.6	%											Plant - Regulated
	Progress Energy		2.5	%		2.6	%		2.3	%												Electric generation, distribution and transmission	2	-	138		73,181		29,269		30,250		18,009		12,041		3,774		8,622
	Duke Energy Progress		2.5	%		2.7	%		2.1	%												Natural gas transmission and distribution	12	-	60		2,026		―		―		―		―		2,026		―
	Duke Energy Florida		2.4	%		2.5	%		2.4	%												Other buildings and improvements	2	-	100		1,319		444		609		283		318		125		149
	Duke Energy Ohio		3.3	%		3.2	%		3.5	%											Plant - Nonregulated
	Duke Energy Indiana		2.8	%		3.3	%		3.4	%												Electric generation, distribution and transmission	2	-	100		6,055		―		―		―		―		3,870		―
																						Other buildings and improvements	9	-	90		2,940		―		―		―		―		191		―
																					Nuclear fuel						2,127		1,277		850		850		―		―		―
							31-Dec-13														Equipment		1	-	34		1,448		279		604		336		90		255		141
	(in millions)		Estimated Useful Life (Years)					Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana	Construction in process						6,655		1,996		1,424		946		474		204		2,836
	Land						$	1,481	$	397	$	705	$	383	$	321	$	137	$	105	Other		5	-	60		3,272		547		791		380		270		243		174
	Plant - Regulated																				Total property, plant and equipment^(a)(d)						100,391		34,190		35,146		21,184		13,432		10,824		12,012
		Electric generation, distribution and transmission	2	-	125			78,272		30,018		31,792		19,190		12,601		3,925		11,594	Total accumulated depreciation - regulated^(b)(c)(d)						-29,471		-11,437		-12,512		-8,185		-4,072		-1,995		-3,692
		Natural gas transmission and distribution	12	-	67			2,138		―		―		―		―		2,138		―	Total accumulated depreciation - nonregulated^(c)(d)						-2,498		―		―		―		―		-703		―
		Other buildings and improvements	2	-	100			1,397		447		610		282		315		190		159	Generation facilities to be retired, net						136		73		63		63		―		―		―
	Plant - Nonregulated																				Total net property, plant and equipment					$	68,558	$	22,826	$	22,697	$	13,062	$	9,360	$	8,126	$	8,320
		Electric generation, distribution and transmission	2	-	100			6,267		―		―		―		―		4,017		―
		Other buildings and improvements	9	-	100			2,512		―		―		―		―		5		―	(a)	Includes capitalized leases of $1,844 million, $53 million, $339 million, $150 million, $189 million, $86 million, and $28 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $49 million, an insignificant amount and $48 million, respectively, of accumulated amortization of capitalized leases.
	Nuclear fuel							2,458		1,446		1,012		1,012		―		―		―	(b)	Includes $857 million, $557 million, $300 million and $300 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.
	Equipment		1	-	33			1,557		287		621		357		94		317		146	(c)	Includes accumulated amortization of capitalized leases of $34 million, $3 million, $12 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.
	Construction in process							3,595		1,741		873		631		238		166		307	(d)	Includes gross property, plant and equipment cost of consolidated VIEs of $1,558 million and accumulated depreciation of consolidated VIEs of $103 million at Duke Energy.
	Other		5	-	33			3,438		570		867		418		294		248		178
	Total property, plant and equipment^(a)(d)							103,115		34,906		36,480		22,273		13,863		11,143		12,489
	Total accumulated depreciation - regulated^(b)(c)(d)							-31,659		-11,894		-13,098		-8,623		-4,252		-2,160		-3,913
	Total accumulated depreciation - nonregulated^(c)(d)							-1,966		―		―		―		―		-748		―
	Total net property, plant and equipment						$	69,490	$	23,012	$	23,382	$	13,650	$	9,611	$	8,235	$	8,576

	(a)	Includes capitalized leases of $1,606 million, $53 million, $328 million, $148 million, $180 million, $96 million, and $30 million at Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, respectively, primarily in regulated plant. The Progress Energy, Duke Energy Progress and Duke Energy Florida amounts are net of $60 million, an insignificant amount and $57 million, respectively, of accumulated amortization of capitalized leases.
	(b)	Includes $1,118 million, $681 million, $438 million and $438 million of accumulated amortization of nuclear fuel at Duke Energy, Duke Energy Carolinas, Progress Energy and Duke Energy Progress, respectively.
	(c)	Includes accumulated amortization of capitalized leases of $40 million, $4 million, $21 million and $5 million at Duke Energy, Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana, respectively.
	(d)	Includes gross property, plant and equipment cost of consolidated VIEs of $1,678 million and accumulated depreciation of consolidated VIEs of $175 million at Duke Energy.

Schedule Of Capitalized Interest	'																				'
	The following table presents capitalized interest, which includes the debt component of AFUDC.

			Years Ended December 31,
	(in millions)			2013		2012		2011
	Duke Energy		$	90	$	177	$	166
	Duke Energy Carolinas			41		72		78
	Progress Energy			19		41		35
	Duke Energy Progress			16		23		20
	Duke Energy Florida			3		18		15
	Duke Energy Ohio			12		15		9
	Duke Energy Indiana			9		39		33

Goodwill_and_Intangible_Assets1

Goodwill and Intangible Assets (Tables)	12 Months Ended
Goodwill and Intangible Assets (Tables)	Dec. 31, 2013																				Dec. 31, 2012
Goodwill [Line Items]	'																				'
Goodwill By Reportable Operating Segment	'																				'
	Acquisitions ^(a)				2			-5			2			-1							(in millions)		Regulated Utilities			International Energy			Commercial Power			Total
	Foreign exchange and other changes				-2			-22			―			-24							Balance at December 31, 2012
	Balance at December 31, 2013																				Goodwill		$	15,950		$	353		$	933		$	17,236
	Goodwill				15,950			326			935			17,211							Accumulated impairment charges			―			―			-871			-871
	Accumulated impairment charges				―			―			-871			-871							Balance at December 31, 2012, as adjusted for accumulated impairment charges			15,950			353			62			16,365
	Balance at December 31, 2013, as adjusted for accumulated impairment charges			$	15,950		$	326		$	64		$	16,340

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

Schedule of Intangible Assets	'																				'
																						31-Dec-12
			31-Dec-13																		(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		Emission allowances	$	80		$	―		$	26		$	4		$	22	$	24	$	29
	Emission allowances		$	63		$	1		$	21		$	3		$	18	$	20	$	21	Renewable energy certificates		18			14			2			1			―		―		―
	Renewable energy certificates			82			16			64			64			―		2		―	Gas, coal and power contracts		295			―			―			―			―		272		24
	Gas, coal and power contracts			180			―			―			―			―		156		24	Wind development rights		111			―			―			―			―		―		―
	Wind development rights			86			―			―			―			―		―		―	Other		91			―			―			―			―		10		―
	Other			76			―			―			―			―		―		―	Total gross carrying amounts		595			14			28			5			22		306		53
	Total gross carrying amounts			487			17			85			67			18		178		45	Accumulated amortization - gas, coal and power contracts		-180			―			―			―			―		-168		-12
	Accumulated amortization - gas, coal and power contracts			-73			―			―			―			―		-60		-13	Accumulated amortization - wind development rights		-9			―			―			―			―		―		―
	Accumulated amortization - wind development rights			-12			―			―			―			―		―		―	Accumulated amortization - other		-34			―			―			―			―		-9		―
	Accumulated amortization - other			-24			―			―			―			―		―		―	Total accumulated amortization		-223			―			―			―			―		-177		-12
	Total accumulated amortization			-109			―			―			―			―		-60		-13	Total intangible assets, net	$	372		$	14		$	28		$	5		$	22	$	129	$	41
	Total intangible assets, net		$	378		$	17		$	85		$	67		$	18	$	118	$	32

Schedule of Amortization Expense	'																				'
	Amortization Expense

	The following table presents amortization expense for gas, coal and power contracts, wind development rights and other intangible assets.

			December 31,
	(in millions)			2013			2012			2011
	Duke Energy		$	13		$	14		$	10
	Duke Energy Ohio			8			12			8
	Duke Energy Indiana			1			1			1

Schedule of Expected Amortization Expense	'																				'

	(in millions)			2014			2015			2016			2017			2018
	Duke Energy		$	43		$	19		$	17		$	16		$	16
	Progress Energy			4			3			2			1			1
	Duke Energy Progress			1			―			―			―			―
	Duke Energy Florida			3			3			2			1			1
	Duke Energy Ohio			11			9			9			9			9
	Duke Energy Indiana			22			1			1			1			1

Duke Energy Ohio [Member]	'																				'
Goodwill [Line Items]	'																				'
Goodwill By Reportable Operating Segment	'																				'
	Foreign exchange and other changes			-1			―			-1											(in millions)	Regulated Utilities			Commercial Power			Total
	Balance at December 31, 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 December 31, 2013, as adjusted for accumulated impairment charges		$	920		$	―		$	920											Balance at December 31, 2012, as adjusted for accumulated impairment charges		921			―			921

Investments_in_Unconsolidated_1

Investments in Unconsolidated Affiliates (Tables)	12 Months Ended
Investments in Unconsolidated Affiliates (Tables)	Dec. 31, 2013
Investments In Unconsolidated Affiliates [Line Items]	'
Investments in Equity Method Unconsolidated Affiliates	'

		Years Ended December 31,
		2013				2012				2011
	(in millions)	Investments		Equity in earnings		Investments		Equity in earnings		Equity in earnings
	Regulated Utilities	$	4	$	-1	$	5	$	-5	$	—
	International Energy		82		110		81		134		145
	Commercial Power		252		7		219		14		6
	Other		52		6		178		5		9
	Total	$	390	$	122	$	483	$	148	$	160

Related_Party_Transactions_Tab

Related Party Transactions (Tables)	12 Months Ended
Related Party Transactions (Tables)	Dec. 31, 2013
Duke Energy Carolinas [Member]	'
Related Party Transaction [Line Items]	'
Related Party Transactions, Other Revenue and Expense	'

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 Statements of Operations and Comprehensive Income.

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

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 Statements of Operations and Comprehensive Income.

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

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 Statements of Operations and Comprehensive Income.

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

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 Statements of Operations and Comprehensive Income.

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

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 Statements of Operations and Comprehensive Income.

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

			Years Ended December 31,
	(in millions)		2013		2012		2011
	Duke Energy Carolinas
	Corporate governance and shared service expenses^(a)		$	927	$	1,112	$	1,009
	Indemnification coverages^(b)			22		21		21
	Joint Dispatch Agreement (JDA) revenue^(c)			121		18		―
	Joint Dispatch Agreement (JDA) expense^(c)			116		91		―
	Progress Energy
	Corporate governance and shared services provided by Duke Energy^(a)		$	290	$	63	$	―
	Corporate governance and shared services provided to Duke Energy^(d)			96		47		―
	Indemnification coverages^(b)			34		17		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Progress
	Corporate governance and shared service expenses^(a)		$	266	$	254	$	203
	Indemnification coverages^(b)			20		8		―
	JDA revenue^(c)			116		91		―
	JDA expense^(c)			121		18		―
	Duke Energy Florida
	Corporate governance and shared service expenses^(a)		$	182	$	186	$	160
	Indemnification coverages^(b)			14		8		―
	Duke Energy Ohio
	Corporate governance and shared service expenses^(a)		$	347	$	358	$	401
	Indemnification coverages^(b)			15		15		17
	Duke Energy Indiana
	Corporate governance and shared service expenses^(a)		$	422	$	419	$	415
	Indemnification coverages^(b)			14		8		7

	(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other costs by unconsolidated affiliates that 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 Consolidated Statements of Operations and Comprehensive Income. See Note 21 for additional information.
	(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 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 service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues and expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the 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 Statements of Operations and Comprehensive Income.

Derivatives_and_Hedging_Tables

Derivatives and Hedging (Tables)	12 Months Ended
Derivatives and Hedging (Tables)	Dec. 31, 2013																			Dec. 31, 2012
Derivative [Line Items]	'																			'
Notional Amounts Of Derivative Instruments Related To Interest Rate Risk	'																			'

			31-Dec-13					31-Dec-12
	(in millions)		Duke Energy			Duke Energy Ohio		Duke Energy			Progress Energy			Duke Energy Progress		Duke Energy Ohio		Duke Energy Indiana
	Cash flow hedges^(a)		$	798		$	―	$	1,047		$	―		$	―	$	―	$	―
	Undesignated contracts			34			27		290			50			50		27		200
	Fair value hedges			―			―		250			―			―		250		―
		Total notional amount	$	832		$	27	$	1,587		$	50		$	50	$	277	$	200

	(a)	Duke Energy includes amounts related to non-recourse variable rate long-term debt of VIEs of $584 million at December 31, 2013 and $620 million at December 31, 2012.

Underlying Notional Amounts for Commodity Derivative Instruments Accounted for at Fair Value	'																			'
			31-Dec-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 (Gigawatt-hours)^(a)		71,466		1,205		925	925		―		69,362		203						Electricity (Gigawatt-hours)^(a)	52,104		2,028		1,850	1,850		―		51,215		97
	Natural gas (millions of decatherms)		636		―		363	141		222		274		―						Natural gas (millions of decatherms)	528		―		348	118		230		180		―

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


			December 31,
			2013					2012
	(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			27			―		7			―
	Current liabilities: Other			―			18		―			81
	Deferred credits and other liabilities: other			―			4		―			35
	Total Derivatives Designated as Hedging Instruments			27			23		9			119
	Derivatives Not Designated as Hedging Instruments
	Commodity contracts
	Current assets: other			201			158		41			2
	Investments and other assets: other			215			131		106			50
	Current liabilities: other			13			153		106			407
	Deferred credits and other liabilities: other			5			166		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			434			613		255			798
	Total Derivatives		$	461		$	636	$	264		$	917

Offsetting Assets and Liabilities	'																			'
			31-Dec-13																		31-Dec-12
			Derivative Assets						Derivative Liabilities												Derivative Assets						Derivative Liabilities
	(in millions)		Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)								(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)
	Gross amounts recognized		$	214		$	233		$	322		$	299							Gross amounts recognized	$	127		$	96		$	402		$	295
	Gross amounts offset			-179			-138			-192			-155							Gross amounts offset		-114			-54			-151			-90
	Net amount subject to master netting			35			95			130			144							Net amounts subject to master netting		13			42			251			205
	Amounts not subject to master netting			―			14			4			11							Amounts not subject to master netting		22			19			166			54
	Net amounts recognized on the Consolidated Balance Sheet		$	35		$	109		$	134		$	155							Net amounts recognized on the Consolidated Balance Sheet	$	35		$	61		$	417		$	259

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'																			'
	The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations where such gains and losses are included when reclassified from AOCI.

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Pretax Gains (Losses) Recorded in AOCI
	Interest rate contracts^(a)		$	79		$	-23	$	-88
	Commodity contracts			1			1		―
	Total Pretax Gains (Losses) Recorded in AOCI		$	80		$	-22	$	-88
	Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
	Interest rate contracts
	Interest expense		$	-2		$	2	$	-5
	Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	-2		$	2	$	-5

	(a)	Reclassified to earnings as 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	'																			'

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Revenue: Regulated electric		$	11		$	-23	$	―
	Revenue: Nonregulated electric, natural gas and other			43			38		-59
	Other income and expenses			―			-2		―
	Fuel used in electric generation and purchased power-regulated			-200			-194		―
	Fuel used in electric generation and purchased power - nonregulated			-100			2		-1
	Interest rate contracts
	Interest expense			-18			-8		―
	Total Pretax (Losses) Gains Recognized in Earnings		$	-264		$	-187	$	-60
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(a)
	Regulatory assets		$	10		$	-2	$	-1
	Regulatory liabilities			15			36		17
	Interest rate contracts^(b)
	Regulatory assets			55			10		-165
	Regulatory liabilities			―			―		-60
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	80		$	44	$	-209

	(a)	Reclassified to earnings to match recovery through the fuel clause.
	(b)	Reclassified to earnings as interest expense over the term of the related debt.

Schedule Of Information Regarding Derivative Instruments That Contain Credit-Risk Related Contingent Features	'																			'
			31-Dec-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		$	525		$	168	$	60		$	108		$	355					Aggregate fair value amounts of derivative instruments in a net liability position	$	466		$	286	$	108		$	178		$	176
	Fair value of collateral already posted			135			10		―			10			125					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			205			158		60			98			47					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	'																			'

			December 31,
			2013					2012
	(in millions)		Receivables			Payables		Receivables			Payables
	Duke Energy
	Amounts offset against net derivative positions		$	30		$	―	$	73		$	―
	Amounts not offset against net derivative positions			122			―		93			―
	Progress Energy
	Amounts offset against net derivative positions		$	10		$	―	$	58		$	―
	Amounts not offset against net derivative positions			―			―		1			―
	Duke Energy Progress
	Amounts offset against net derivative positions		$	―		$	―	$	9		$	―
	Amounts not offset against net derivative positions			―			―		―			―
	Duke Energy Florida
	Amounts offset against net derivative positions		$	10		$	―	$	49		$	―
	Amounts not offset against net derivative positions			―			―		1			―
	Duke Energy Ohio
	Amounts offset against net derivative positions		$	19			―	$	15		$	―
	Amounts not offset against net derivative positions			115		$	―		92			―
	Duke Energy Indiana
	Amounts offset against net derivative positions			―			1		―			―
	Amounts not offset against net derivative positions		$	1		$	―	$	―		$	―

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

			December 31,
			2013					2012
	(in millions)		Asset			Liability		Asset			Liability
	Derivatives Not Designated as Hedging Instruments
	Commodity contracts
	Current liabilities: other			―			1		―			6
	Deferred credits and other liabilities: other			―			1		―			6
	Total Derivatives Not Designated as Hedging Instruments			―			2		―			12
	Total Derivatives		$	―		$	2	$	―		$	12

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

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'																			'
	The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income where such gains and losses are included when reclassified from AOCI.

	Losses on cash flow hedges reclassified at Duke Energy Carolinas during the year ended December 31, 2013 and 2012 were not material.

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
	Interest rate contracts
	Interest expense		$	-3		$	-3	$	-5
	Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	-3		$	-3	$	-5

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

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Revenue: Regulated electric		$	-12		$	-12	$	―
	Total Pretax (Losses) Gains Recognized in Earnings		$	-12		$	-12	$	―
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Interest rate contracts
	Regulatory assets		$	―		$	―	$	-94
	Regulatory liabilities			―			―		-60
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	―		$	―	$	-154

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

			December 31,
			2013					2012
	(in millions)		Asset			Liability		Asset			Liability
	Derivatives Designated as Hedging Instruments
	Commodity contracts
	Current liabilities: other		$	―		$	1	$	―		$	2
	Deferred credits and other liabilities: other			―			4		―			1
	Total Derivatives Designated as Hedging Instruments			―			5		―			3
	Derivatives Not Designated as Hedging Instruments
	Commodity contracts
	Current assets: other			3			2		3			―
	Investments and other assets: other			2			1		8			―
	Current liabilities: other			11			105		―			231
	Deferred credits and other liabilities: other			4			91		―			195
	Interest rate contracts
	Current liabilities: other			―			―		―			11
	Total Derivatives Not Designated as Hedging Instruments			20			199		11			437
	Total Derivatives		$	20		$	204	$	11		$	440

Offsetting Assets and Liabilities	'																			'
			31-Dec-13																		31-Dec-12
			Derivative Assets						Derivative Liabilities												Derivative Assets						Derivative Liabilities
	(in millions)		Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)								(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)
	Gross amounts recognized		$	15		$	5		$	107		$	93							Gross amounts recognized	$	3		$	8		$	244		$	192
	Gross amounts offset			-13			-4			-17			-10							Gross amounts offset		―			―			-22			-36
	Net amount subject to master netting			2			1			90			83							Net amounts 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 Consolidated Balance Sheet		$	2		$	1		$	90		$	87							Net amounts recognized on the Consolidated Balance Sheet	$	3		$	8		$	222		$	160

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'																			'
	The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheet where such gains and losses are included when reclassified from AOCI.

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Pretax Gains (Losses) Recorded in AOCI
	Commodity contracts		$	1		$	1	$	-3
	Interest rate contracts^(a)			―			-11		-141
	Total Pretax Gains (Losses) Recorded in AOCI		$	1		$	-10	$	-144
	Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
	Interest rate contracts
	Interest expense		$	―		$	-14	$	-13
	Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	―		$	-14	$	-13
	Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets or Liabilities^(b)
	Interest rate contracts
	Regulatory assets		$	―		$	-159	$	―
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	―		$	-159	$	―

	(a)	Reclassified to earnings as interest expense over the term of the related debt.
	(b)	Effective with the merger, Progress Energy no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

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

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Operating revenues		$	11		$	-11	$	1
	Fuel used in electric generation and purchased power			-200			-454		-297
	Other income and expenses, net			―			7		-59
	Interest rate contracts
	Interest expense			-17			-8		―
	Total Pretax (Losses) Gains Recognized in Earnings		$	-206		$	-466	$	-355
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(a)
	Regulatory assets		$	10		$	-171	$	-502
	Interest rate contracts^(b)
	Regulatory assets			18			6		―
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	28		$	-165	$	-502

	(a)	Reclassified to earnings to match recovery through the fuel clause.
	(b)	Reclassified to earnings as interest expense over the term of the related debt.

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

			December 31,
			2013					2012
	(in millions)		Asset			Liability		Asset			Liability
	Derivatives Designated as Hedging Instruments
	Commodity contracts
	Current liabilities: other		$	―		$	1	$	―		$	1
	Deferred credits and other liabilities: other			―			―		―			1
	Total Derivatives Designated as Hedging Instruments			―			1		―			2
	Derivatives Not Designated as Hedging Instruments
	Commodity contracts^(a)
	Current assets: other			―			―		1			―
	Investments and other assets: other			2			1		1			―
	Current liabilities: other			2			40		―			85
	Deferred credits and other liabilities: other			2			29		―			68
	Interest rate contracts
	Current liabilities: other			―			―		―			11
	Total Derivatives Not Designated as Hedging Instruments			6			70		2			164
	Total Derivatives		$	6		$	71	$	2		$	166

	(a)	Substantially all of these contracts are recorded as regulatory assets or liabilities.

Offsetting Assets and Liabilities	'																			'
			31-Dec-13																		31-Dec-12
			Derivative Assets						Derivative Liabilities												Derivative Assets						Derivative Liabilities
	(in millions)		Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)								(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)
	Gross amounts recognized		$	3		$	3		$	41		$	30							Gross amounts recognized	$	1		$	1		$	97		$	69
	Gross amounts offset			-3			-3			-3			-3							Gross amounts offset		―			―			-2			-7
	Net amount subject to master netting			―			―			38			27							Net amounts subject to master netting		1			1			95			62
	Net amounts recognized on the Consolidated Balance Sheet		$	―		$	―		$	38		$	27							Net amounts recognized on the Consolidated Balance Sheet	$	1		$	1		$	95		$	62

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'																			'
	The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheets in which such gains and losses are included when reclassified from AOCI.

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Pretax Gains (Losses) Recorded in AOCI
	Interest rate contracts^(a)		$	―		$	-7	$	-70
	Total Pretax Gains (Losses) Recorded in AOCI		$	―		$	-7	$	-70
	Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
	Interest rate contracts
	Interest expense		$	―		$	-5	$	-7
	Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	―		$	-5	$	-7
	Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets or Liabilities^(b)
	Interest rate contracts
	Regulatory assets		$	―		$	-117	$	―
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	―		$	-117	$	―

	(a)	Reclassified to earnings as interest expense over the term of the related debt.
	(b)	Effective with the merger, Duke Energy Progress no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

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

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Operating revenues		$	11		$	-11	$	1
	Fuel used in electric generation and purchased power			-71			-115		-60
	Interest rate contracts
	Interest expense			-13			-6		―
	Total Pretax (Losses) Gains Recognized in Earnings		$	-73		$	-132	$	-59
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(a)
	Regulatory assets		$	-6		$	-55	$	-140
	Interest rate contracts^(b)
	Regulatory assets			13			6		―
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	7		$	-49	$	-140

	(a)	Reclassified to earnings to match recovery through the fuel clause.
	(b)	Reclassified to earnings as interest expense over the term of the related debt.

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

			December 31,
			2013					2012
	(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			3			2		2			―
	Investments and other assets: other			―			―		7			―
	Current liabilities: other			9			64		―			146
	Deferred credits and other liabilities: other			2			63		―			123
	Total Derivatives Not Designated as Hedging Instruments			14			129		9			269
	Total Derivatives		$	14		$	129	$	9		$	270

	(a)	Substantially all of these contracts are recorded as regulatory assets or liabilities.

Offsetting Assets and Liabilities	'																			'
			31-Dec-13																		31-Dec-12
			Derivative Assets						Derivative Liabilities												Derivative Assets						Derivative Liabilities
	(in millions)		Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)								(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)
	Gross amounts recognized		$	12		$	2		$	66		$	63							Gross amounts recognized	$	2		$	7		$	147		$	123
	Gross amounts offset			-10			-2			-15			-7							Gross amounts offset		―			―			-20			-29
	Net amount subject to master netting			2			―			51			56							Net amounts subject to master netting		2			7			127			94
	Net amounts recognized on the Consolidated Balance Sheet		$	2		$	―		$	51		$	56							Net amounts recognized on the Consolidated Balance Sheet	$	2		$	7		$	127		$	94

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'																			'
	The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income or Consolidated Balance Sheets in which such gains and losses are included when reclassified from AOCI.

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Pretax Gains (Losses) Recorded in AOCI
	Commodity contracts		$	1		$	1	$	-3
	Interest rate contracts^(a)			―			-2		-35
	Total Pretax Gains (Losses) Recorded in AOCI		$	1		$	-1	$	-38
	Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
	Interest rate contracts
	Interest expense		$	―		$	-2	$	-1
	Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	―		$	-2	$	-1
	Location of Pretax Gains and (Losses) Reclassified from AOCI to Regulatory Assets^(b)
	Interest rate contracts
	Regulatory assets		$	―		$	-42	$	―
	Total Pretax Gains (Losses) Reclassified from AOCI to Regulatory Assets		$	―		$	-42	$	―

	(a)	Reclassified to earnings as interest expense over the term of the related debt.
	(b)	Effective with the merger, Duke Energy Florida no longer designates interest rate derivatives for regulated operations as cash flow hedges. As a result, the pretax losses on derivatives as of the date of the merger were reclassified from AOCI to Regulatory assets.

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

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Fuel used in electric generation and purchased power		$	-129		$	-339	$	-237
	Interest rate contracts
	Interest expense			-5			-2		―
	Total Pretax (Losses) Gains Recognized in Earnings		$	-134		$	-341	$	-237
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(a)
	Regulatory assets		$	16		$	-116	$	-362
	Interest rate contracts
	Regulatory assets			5			―		―
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	21		$	-116	$	-362

	(a)	Reclassified to earnings to match recovery through the fuel clause.

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

			December 31,
			2013					2012
	(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			186			163		31			4
	Investments and other assets: other			202			130		81			51
	Current liabilities: other			1			36		106			132
	Deferred credits and other liabilities: other			2			56		―			4
	Interest rate contracts
	Current liabilities: other			―			1		―			1
	Deferred credits and other liabilities: other			―			4		―			7
	Total Derivatives Not Designated as Hedging Instruments			391			390		218			199
	Total Derivatives		$	391		$	390	$	220		$	199

Offsetting Assets and Liabilities	'																			'
			31-Dec-13																		31-Dec-12
			Derivative Assets						Derivative Liabilities												Derivative Assets						Derivative Liabilities
	(in millions)		Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)								(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)
	Gross amounts recognized		$	186		$	205		$	199		$	186							Gross amounts recognized	$	137		$	81		$	136		$	55
	Gross amounts offset			-165			-132			-173			-143							Gross amounts offset		-110			-51			-125			-51
	Net amount subject to master netting			21			73			26			43							Net amounts 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 Consolidated Balance Sheet		$	21		$	73		$	27		$	47							Net amounts recognized on the Consolidated Balance Sheet	$	29		$	30		$	12		$	11

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

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Revenue: Nonregulated electric, natural gas and other		$	44		$	76	$	-26
	Fuel used in electric generation and purchased power - nonregulated			-100			2		-1
	Interest rate contracts
	Interest expense			-1			-1		-1
	Total Pretax (Losses) Gains Recognized in Earnings		$	-57		$	77	$	-28
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts
	Regulatory assets		$	―		$	2	$	1
	Regulatory liabilities			―			-1		―
	Interest rate contracts
	Regulatory assets			4			―		-4
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	4		$	1	$	-3

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


			December 31,
			2013					2012
	(in millions)		Asset			Liability		Asset			Liability
	Derivatives Not Designated as Hedging Instruments
	Commodity contracts
	Current assets: other		$	12		$	―	$	10		$	―
	Interest rate contracts
	Current liabilities: other			―			―		―			63
	Total Derivatives Not Designated as Hedging Instruments			12			―		10			63
	Total Derivatives		$	12		$	―	$	10		$	63

Offsetting Assets and Liabilities	'																			'
			31-Dec-13																		31-Dec-12
			Derivative Assets						Derivative Liabilities												Derivative Assets						Derivative Liabilities
	(in millions)		Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)								(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)
	Gross amounts recognized		$	12		$	―		$	―		$	―							Amounts not subject to master netting	$	10		$	―		$	63		$	―
	Gross amounts offset			-1			―			―			―							Net amounts recognized on the Consolidated Balance Sheet	$	10		$	―		$	63		$	―
	Net amount subject to master netting			11			―			―			―
	Net amounts recognized on the Consolidated Balance Sheet		$	11		$	―		$	―		$	―

Cash Flow Hedges-Location And Amount Of Pre-Tax (Losses) Recognized In Comprehensive Income	'																			'
	The following table shows the gains and losses during the year recognized on cash flow hedges and the line items on the Consolidated Statements of Operations and Comprehensive Income where such gains and losses are included when reclassified from AOCI.

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Reclassified from AOCI into Earnings
	Interest rate contracts
	Interest expense		$	3		$	3	$	2
	Total Pretax Gains (Losses) Reclassified from AOCI into Earnings		$	3		$	3	$	2

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

			Years Ended December 31,
	(in millions)		2013			2012		2011
	Location of Pretax Gains and (Losses) Recognized in Earnings
	Commodity contracts
	Revenue, regulated electric		$	1		$	―	$	―
	Total Pretax (Losses) Gains Recognized in Earnings		$	1		$	―	$	―
	Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
	Commodity contracts^(a)
	Regulatory assets		$	―		$	2	$	-2
	Regulatory liabilities			16			35		17
	Interest rate contracts^(b)
	Regulatory assets			34			4		-67
	Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities		$	50		$	41	$	-52

	(a)	Reclassified to earnings to match recovery through the fuel clause.
	(b)	Reclassified to earnings as interest expense over the term of the related debt.

Investments_in_Debt_and_Equity1

Investments in Debt and Equity Securities (Tables)	12 Months Ended
Investments in Debt and Equity Securities (Tables)	Dec. 31, 2013
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'

	DUKE ENERGY

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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		$	—		$	—		$	110		$	—	$	—	$	105
	Equity securities			1,813			10			3,579			1,132		19		2,837
	Corporate debt securities			8			6			400			21		1		338
	Municipal bonds			2			6			160			12		1		194
	U.S. government bonds			7			12			730			24		1		625
	Other debt securities			22			2			154			10		1		164
	Total NDTF			1,852			36			5,133			1,199		23		4,263
	Other Investments
	Cash and cash equivalents			—			—			21			—		—		17
	Equity securities			29			—			91			10		—		63
	Corporate debt securities			1			1			99			2		—		381
	Municipal bonds			2			2			79			4		1		70
	U.S. government bonds			—			—			17			—		—		23
	Other debt securities			—			8			111			1		6		115
	Total Other Investments^(a)			32			11			418			17		7		669
	Total Investments		$	1,884		$	47		$	5,551		$	1,216	$	30	$	4,932

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

Schedule of Maturity Dates for Debt Securities	'
	The table below summarizes the maturity date for debt securities.

	(in millions)		31-Dec-13
	Due in one year or less		$	89
	Due after one through five years			431
	Due after five through 10 years			426
	Due after 10 years			804
	Total		$	1,750

Schedule of Realized Gain (Loss)	'
	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.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Realized gains		$	209		$	117		$	79
	Realized losses			65			19			37

Duke Energy Carolinas [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
	DUKE ENERGY CAROLINAS

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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		$	―		$	―		$	42		$	―	$	―	$	40
	Equity securities			974			6			1,964			600		5		1,592
	Corporate debt securities			5			5			274			11		1		250
	Municipal bonds			―			2			54			2		―		40
	U.S. government bonds			3			7			354			10		―		304
	Other debt securities			22			2			146			9		2		135
	Total NDTF			1,004			22			2,834			632		8		2,361
	Other Investments
	Other debt securities			―			1			3			―		1		3
	Total Other Investments^(a)			―			1			3			―		1		3
	Total Investments		$	1,004		$	23		$	2,837		$	632	$	9	$	2,364

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

Schedule of Maturity Dates for Debt Securities	'
	The table below summarizes the maturity date for debt securities.

	(in millions)		31-Dec-13
	Due in one year or less		$	18
	Due after one through five years			167
	Due after five through 10 years			239
	Due after 10 years			407
	Total		$	831


Schedule of Realized Gain (Loss)	'
	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.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Realized gains		$	115		$	89		$	71
	Realized losses			12			6			35

Progress Energy [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
	PROGRESS ENERGY

	The following table presents the estimated fair value of investments in available-for-sale securities for Progress Energy.

			31-Dec-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		$	―		$	―		$	68		$	―	$	―	$	65
	Equity securities			839			4			1,615			532		14		1,245
	Corporate debt securities			3			1			126			9		―		89
	Municipal bonds			2			4			106			11		1		154
	U.S. government bonds			4			5			376			14		―		321
	Other debt securities			―			―			8			1		―		28
	Total NDTF			848			14			2,299			567		15		1,902
	Other Investments
	Cash and cash equivalents			―			―			20			―		―		17
	Municipal bonds			1			―			39			3		―		40
	Total Other Investments^(a)			1			―			59			3		―		57
	Total Investments		$	849		$	14		$	2,358		$	570	$	15	$	1,959

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

Schedule of Maturity Dates for Debt Securities	'
	The table below summarizes the maturity date for debt securities.

	(in millions)		31-Dec-13
	Due in one year or less		$	12
	Due after one through five years			206
	Due after five through 10 years			131
	Due after 10 years			306
	Total		$	655

Schedule of Realized Gain (Loss)	'
	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.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Realized gains		$	90		$	34		$	30
	Realized losses			46			18			33

Duke Energy Progress [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
	DUKE ENERGY PROGRESS

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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		$	―		$	―		$	48		$	―	$	―	$	55
	Equity securities			535			3			1,069			337		11		811
	Corporate debt securities			3			1			80			8		―		78
	Municipal bonds			2			4			104			4		―		80
	U.S. government bonds			4			3			232			13		―		241
	Other debt securities			―			―			5			1		―		10
	Total NDTF			544			11			1,538			363		11		1,275
	Other Investments
	Cash and cash equivalents			―			―			2			―		―		3
	Total Other Investments^(a)			―			―			2			―		―		3
	Total Investments		$	544		$	11		$	1,540		$	363	$	11	$	1,278

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

Schedule of Maturity Dates for Debt Securities	'
	The table below summarizes the maturity date for debt securities.

	(in millions)		31-Dec-13
	Due in one year or less		$	7
	Due after one through five years			122
	Due after five through 10 years			89
	Due after 10 years			203
	Total		$	421

Schedule of Realized Gain (Loss)	'
	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.

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Realized gains		$	58		$	21		$	13
	Realized losses			26			8			16

Duke Energy Florida [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
	DUKE ENERGY FLORIDA

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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		$	―		$	―		$	20		$	―	$	―	$	10
	Equity securities			304			1			546			194		4		434
	Corporate debt securities			―			―			46			1		―		11
	Municipal bonds			―			―			2			7		―		74
	U.S. government bonds			―			2			144			1		―		80
	Other debt securities			―			―			3			1		―		18
	Total NDTF			304			3			761			204		4		627
	Other Investments
	Cash and cash equivalents			―			―			3			―		―		1
	Municipal bonds			1			―			39			3		―		40
	Total Other Investments^(a)			1			―			42			3		―		41
	Total Investments		$	305		$	3		$	803		$	207	$	4	$	668

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

Schedule of Maturity Dates for Debt Securities	'
	The table below summarizes the maturity date for debt securities.

	(in millions)		31-Dec-13
	Due in one year or less		$	5
	Due after one through five years			84
	Due after five through 10 years			42
	Due after 10 years			103
	Total		$	234

Schedule of Realized Gain (Loss)	'
	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.

				Years Ended December 31,
	(in millions)			2013			2012			2011
	Realized gains			$	32		$	13		$	17
	Realized losses				20			9			17

Duke Energy Indiana [Member]	'
Schedule of Investments [Line Items]	'
Available-For-Sale Investments	'
	DUKE ENERGY INDIANA

	The following table presents the estimated fair value of investments in available-for-sale securities.

			31-Dec-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
	Cash and cash equivalents		$	―		$	―		$	1		$	―	$	―	$	―
	Equity securities			24			―			65			9		―		50
	Municipal bonds			―			1			28			1		―		28
	Total Other Investments^(a)			24			1			94			10		―		78
	Total Investments		$	24		$	1		$	94		$	10	$	―	$	78

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

Schedule of Maturity Dates for Debt Securities	'
	The table below summarizes the maturity date for debt securities held by Duke Energy Indiana.

	(in millions)		31-Dec-13
	Due in one year or less		$	1
	Due after one through five years			21
	Due after five through 10 years			4
	Due after 10 years			2
	Total		$	28

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
Fair Value Measurements (Tables)	Dec. 31, 2013													Dec. 31, 2012													Dec. 31, 2011
Fair Value Disclosures [Line Items]	'													'													'
Fair Value Measurement Amounts For Assets And Liabilities	'													'													'

			31-Dec-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		$	3,579		$	3,495		$	57		$	27	Nuclear decommissioning trust fund equity securities		$	2,837		$	2,762		$	54		$	21
	Nuclear decommissioning trust fund debt securities			1,553			402			1,100			51	Nuclear decommissioning trust fund debt securities			1,405			317			1,040			48
	Other trading and available-for-sale equity securities^(a)			102			91			11			―	Other trading and available-for-sale equity securities^(a)			72			63			9			―
	Other trading and available-for-sale debt securities^(b)			333			36			277			20	Other trading and available-for-sale debt securities^(b)			631			40			562			29
	Derivative assets^(a)			145			33			70			42	Derivative assets^(a)			103			18			22			63
		Total assets		5,712			4,057			1,515			140		Total assets		5,048			3,200			1,687			161
	Derivative liabilities^(c)			-321			11			-303			-29	Derivative liabilities^(d)			-756			-17			-591			-148
		Net assets	$	5,391		$	4,068		$	1,212		$	111		Net assets	$	4,292		$	3,183		$	1,096		$	13

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

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'													'													'
	The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.
																31-Dec-12													31-Dec-11
			31-Dec-13											(in millions)			Investments			Derivatives (net)			Total				(in millions)			Investments		Derivatives (net)		Total
	(in millions)			Investments			Derivatives (net)			Total				Balance at December 31, 2011			$	124		$	-39		$	85			Balance at December 31, 2010			$	165	$	-19	$	146
	Balance at December 31, 2012			$	98		$	-85		$	13			Amounts acquired in Progress Energy Merger				―			-30			-30			Total pretax realized or unrealized gains (losses) included in earnings				―		-14		-14
	Total pretax realized or unrealized gains (losses) included in earnings^(a)				―			-42			-42			Total pretax realized or unrealized gains (losses) included in earnings				―			8			8			Total pretax gains included in other comprehensive income				12		―		12
	Purchases, sales, issuances and settlements:													Total pretax gains included in other comprehensive income				13			―			13			Net purchases, sales, issuances and settlements:
		Purchases			9			21			30			Purchases, sales, issuances and settlements:														Purchases			8		8		16
		Sales			-6			―			-6				Purchases			14			22			36				Sales			-3		―		-3
		Issuances			―			11			11				Sales			-2			―			-2				Settlements			-16		-16		-32
		Settlements			-9			25			16				Issuances			―			-15			-15			Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				-42		2		-40
	Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				6			-3			3				Settlements			-55			-32			-87			Balance at December 31, 2011			$	124	$	-39	$	85
	Transfers out of Level 3^(b)				―			86			86			Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				4			1			5
	Balance at December 31, 2013			$	98		$	13		$	111			Balance at December 31, 2012			$	98		$	-85		$	13
	Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding			$	―		$	10		$	10

	(a)	Amounts for derivatives are primarily included in Operating Revenues.
	(b)	Transfers reflect derivative contracts becoming observable due to the passage of time.

Schedule of Long-term debt, including current	'													'													'
	OTHER FAIR VALUE DISCLOSURES

	The fair value and book value of long-term debt, including current maturities, is summarized in the following table. Estimates determined are not necessarily indicative of amounts that could have been settled in current markets. Fair value of long-term debt uses Level 2 measurements.

			31-Dec-13						31-Dec-12
	(in millions)		Book Value			Fair Value			Book Value			Fair Value
	Duke Energy		$	40,256		$	42,592		$	39,461		$	44,001
	Duke Energy Carolinas			8,436			9,123			8,741			10,096
	Progress Energy			14,115			15,234			14,428			16,563
	Duke Energy Progress			5,235			5,323			4,840			5,277
	Duke Energy Florida			4,886			5,408			5,320			6,222
	Duke Energy Ohio			2,188			2,237			1,997			2,117
	Duke Energy Indiana			3,796			4,171			3,702			4,268

Quantitative Information Table - Level 3	'													'													'
	QUANTITATIVE INFORMATION ABOUT UNOBSERVABLE INPUTS
																31-Dec-12
	The following table provides quantitative information about the Duke Energy Registrants' derivatives classified as Level 3.													Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range
														Duke Energy
			31-Dec-13											Natural gas contracts		$	-53		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	2.33	$	9.99
	Investment Type		Fair Value (in millions)			Valuation Technique		Unobservable Input	Range					FERC mitigation power sale agreements			-23		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
	Duke Energy													FTRs			11		RTO auction pricing		FTR price - per MWh		23.63	-	39.22
	Natural gas contracts		$	-2		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	3.07	$	5.37		Electricity contracts			-8		Discounted cash flow		Forward electricity curves - price per MWh		24.82	-	77.96
	FERC mitigation power sale agreements			-2		Discounted cash flow		Forward electricity curves - price per MWh		25.79	-	52.38		Capacity contracts			-3		Discounted cash flow		Forward capacity curves - price per MW day		95.16	-	105.36
	Financial transmission rights (FTRs)			12		RTO auction pricing		FTR price - per Megawatt Hour (MWh)		-0.3	-	13.8		Capacity option contracts			3		Discounted cash flow		Forward capacity option curves - price per MW day		4.68	-	77.96
	Electricity contracts			23		Discounted cash flow		Forward electricity curves - price per MWh		20.77	-	58.9		Reserves			-12				Bid-ask spreads, implied volatility, probability of default
	Commodity capacity option contracts			4		Discounted cash flow		Forward capacity option curves - price per MW day		30.4	-	165.1		Total Level 3 derivatives		$	-85
	Reserves			-22				Bid-ask spreads, implied volatility, probability of default						Duke Energy Carolinas
	Total Level 3 derivatives		$	13										FERC mitigation power sale agreements		$	-12		Discounted cash flow		Forward electricity curves - price per MWh	$	25.83	-	48.69
	Duke Energy Carolinas													Progress Energy
	FERC mitigation power sale agreements		$	-2		Discounted cash flow		Forward electricity curves - price per MWh	$	25.79	$	52.38		Natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
	Duke Energy Ohio													FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
	Electricity contracts		$	18		Discounted cash flow		Forward electricity curves - price per MWh	$	20.77	$	58.9		Total Level 3 derivatives		$	-38
	Natural gas contracts			-2		Discounted cash flow		Forward natural gas curves - price per MMBtu		3.07	-	5.37		Duke Energy Progress
	Reserves			-20				Bid-ask spreads, implied volatility, probability of default						Natural gas contracts		$	-27		Discounted cash flow		Forward natural gas curves - price per MMBtu	$	4.07	-	4.45
	Total Level 3 derivatives		$	-4										FERC mitigation power sale agreements			-11		Discounted cash flow		Forward electricity curves - price per MWh		25.83	-	48.69
	Duke Energy Indiana													Total Level 3 derivatives		$	-38
	FTRs		$	12		RTO auction pricing		FTR price - per MWh	$	-0.3	$	13.8		Duke Energy Ohio
														FTRs		$	1		RTO auction pricing		FTR price - per MWh	$	27.17	$	39.22
														Electricity contracts			-1		Discounted cash flow		Forward electricity curves - price per MWh		25.9	-	57.5
														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
														FTRs		$	10		RTO auction 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	'													'													'

				31-Dec-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		$	1,964		$	1,879		$	58		$	27	Nuclear decommissioning trust fund equity securities		$	1,592		$	1,523		$	48		$	21
	Nuclear decommissioning trust fund debt securities			870			168			651			51	Nuclear decommissioning trust fund debt securities			762			155			559			48
	Other available-for-sale debt securities^(a)			3			-			-			3	Other available-for-sale debt securities^(a)			3			―			―			3
		Total assets		2,837			2,047			709			81		Total assets	$	2,357		$	1,678		$	607		$	72
	Derivative liabilities^(b)			-2			―			―			-2	Derivative liabilities^(b)			-12			―			―			-12
		Net assets	$	2,835		$	2,047		$	709		$	79		Net assets	$	2,345		$	1,678		$	607		$	60

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

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'													'													'
	The following tables provide a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.
																31-Dec-12													31-Dec-11
			31-Dec-13														Investments			Derivatives (net)			Total				(in millions)			Investments		Derivatives (net)		Total
				Investments			Derivatives (net)			Total				Balance at December 31, 2011			$	65		$	―		$	65			Balance at December 31, 2010			$	59	$	―	$	59
	Balance at December 31, 2012			$	72		$	-12		$	60			Total pretax gains included in comprehensive income				2			―			2			Purchases, sales, issuances and settlements:
	Purchases, sales, issuances and settlements:													Purchases, sales, issuances and settlements:														Purchases			8		―		8
		Purchases			9			―			9				Purchases			14			―			14				Sales			-3		―		-3
		Sales			-6			―			-6				Issuances			―			-14			-14			Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				1		―		1
		Settlements			―			10			10				Sales			-2			―			-2			Balance at December 31, 2011			$	65	$	―	$	65
	Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				6			―			6				Settlements			-11			2			-9
	Balance at December 31, 2013			$	81		$	-2		$	79			Total gains included on the Consolidated Balance Sheet as regulatory assets or liabilities				4			―			4
	Pretax amounts included in the Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding			$	―		$	-4		$	-4			Balance at December 31, 2012			$	72		$	-12		$	60

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

			31-Dec-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		$	1,615		$	1,615		$	―		$	―	Nuclear decommissioning trust fund equity securities		$	1,245		$	1,239		$	6		$	―
	Nuclear decommissioning trust fund debt securities and other			677			233			444			―	Nuclear decommissioning trust fund debt securities and other			643			162			481			―
	Other trading and available-for-sale debt securities and other^(a)			58			19			39			―	Other trading and available-for-sale debt securities and other^(a)			57			17			40			―
	Derivative assets^(b)			3			―			3			―	Derivative assets^(b)			11			―			11			―
		Total assets		2,353			1,867			486			―		Total assets		1,956			1,418			538			―
	Derivative liabilities^(c)			-187			―			-187			―	Derivative liabilities^(c)			-440			―			-402			-38
		Net assets	$	2,166		$	1,867		$	299		$	―		Net assets	$	1,516		$	1,418		$	136		$	-38

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

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'													'													'
	The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Years Ended December 31,
	(in millions)		2013			2012			2011
	Balance at beginning of period		$	-38		$	-24		$	-36
	Total pretax realized or unrealized gains included in earnings			―			1			―
	Purchases, sales, issuances and settlements:
		Issuances		10			-16			―
		Settlements		―			4			―
	Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			-6			-3			-21
	Transfers out of Level 3^(a)			34			―			33
	Balance at end of period		$	―		$	-38		$	-24
	Pretax amounts included in the Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding		$	11

	(a)	Transfers reflect derivative contracts becoming observable due to the passage of time.

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

			31-Dec-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		$	1,069		$	1,069		$	―		$	―	Nuclear decommissioning trust fund equity securities		$	811		$	811		$	―		$	―
	Nuclear decommissioning trust fund debt securities and other			470			137			333			―	Nuclear decommissioning trust fund debt securities and other			448			119			329			―
	Other trading and available-for-sale debt securities and other^(a)			3			3			―			―	Other trading and available-for-sale debt securities and other^(a)			3			3			―			―
	Derivative assets^(b)			1			―			1			―	Derivative assets^(b)			2			―			2			―
		Total assets		1,543			1,209			334			―		Total assets		1,264			933			331			―
	Derivative liabilities^(c)			-66			―			-66			―	Derivative liabilities^(c)			-166			―			-128			-38
		Net assets	$	1,477		$	1,209		$	268		$	―		Net assets	$	1,098		$	933		$	203		$	-38

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

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'													'													'
	The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Years Ended December 31,
	(in millions)		2013			2012			2011
	Balance at beginning of period		$	-38		$	-24		$	-36
	Total pretax realized or unrealized gains included in earnings			―			1			―
	Purchases, sales, issuances and settlements:
		Issuances		10			-16			―
		Settlements		―			4			―
	Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			-6			-3			-20
	Transfers out of Level 3^(a)			34			―			32
	Balance at end of period		$	―		$	-38		$	-24
	Pretax amounts included in the Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding		$	11

	(a)	Transfers reflect derivative contracts becoming observable due to the passage of time.

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

			31-Dec-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		$	546		$	546		$	―		$	―	Nuclear decommissioning trust fund equity securities		$	435		$	429		$	6		$	―
	Nuclear decommissioning trust fund debt securities and other			214			96			118			―	Nuclear decommissioning trust fund debt securities and other			194			43			151			―
	Other trading and available-for-sale debt securities and other^(a)			40			2			38			―	Other trading and available-for-sale debt securities and other^(a)			43			3			40			―
	Derivative assets^(b)			1			―			1			―	Derivative assets^(b)			9			―			9			―
		Total assets		801			644			157			―		Total assets		681			475			206			―
	Derivative liabilities^(c)			-116			―			-116			―	Derivative liabilities^(c)			-270			―			-270			―
		Net assets	$	685		$	644		$	41		$	―		Net assets	$	411		$	475		$	-64		$	―

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

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

			31-Dec-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)		$	96		$	50		$	21		$	25	Derivative assets^(a)		$	59		$	48		$	2		$	9
	Derivative liabilities^(b)			-95			-1			-65			-29	Derivative liabilities^(b)			-38			-15			-8			-15
		Net assets (liabilities)	$	1		$	49		$	-44		$	-4		Net assets (liabilities)	$	21		$	33		$	-6		$	-6

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

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'													'													'
	The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Years Ended December 31,
	(in millions)		2013			2012			2011
	Balance at beginning of period		$	-6		$	-3		$	13
	Total pretax realized or unrealized gains included in earnings^(a)			-42			-3			-4
	Purchases, sales, issuances and settlements:
		Purchases		1			―			―
		Settlements		―			1			-14
	Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			―			-1			2
	Transfers out of Level 3^(b)			43			―			―
	Balance at end of period		$	-4		$	-6		$	-3

	(a)	Amounts for derivative are primarily included in Operating Revenues.
	(b)	Transfers reflect derivative contracts becoming observable due to the passage of time.

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

			31-Dec-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)		$	65		$	65		$	―		$	―	Available-for-sale equity securities^(a)		$	49		$	49		$	―		$	―
	Available-for-sale debt securities^(a)			29			―			29			―	Available-for-sale debt securities^(a)			29			―			29			―
	Derivative assets^(b)			12			―			―			12	Derivative assets^(b)			10			―			―			10
		Net assets (liabilities)	$	106		$	65		$	29		$	12		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 Consolidated Balance Sheets.
														(b)	Included in Other within Current Assets on the Consolidated Balance Sheets.
														(c)	Included in Other within Current Liabilities and Other within Deferred Credits and Other Liabilities on the Consolidated Balance Sheets.

Reconciliation Of Assets And Liabilities Measured At Fair Value On A Recurring Basis Using Unobservable Inputs	'													'													'
	The following table provides a reconciliation of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements.

			Derivatives (net)
			Years Ended December 31,
	(in millions)		2013			2012			2011
	Balance at beginning of period		$	10		$	4		$	4
	Total pretax realized or unrealized gains included in earnings^(a)			8			36			14
	Purchases, sales, issuances and settlements:
		Purchases		20			―			8
		Sales		―			22			―
		Settlements		-30			-52			-21
	Total losses included on the Consolidated Balance Sheet as regulatory assets or liabilities			4			―			-1
	Balance at end of period		$	12		$	10		$	4

	(a)	Amounts in derivatives are primarily included in Operating Revenues.

Variable_Interest_Entities_Tab

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

			31-Dec-13																						31-Dec-12
	(in millions)		DERF^(a)			DEPR^(b)			CRC			CinCapV			Renewables			Other			Total		(in millions)		DERF^(a)		CRC		CinCapV			Renewables			Other			Total
	ASSETS																						ASSETS
	Current Assets																						Current Assets
	Restricted receivables of variable interest entities		$	673		$	416		$	595		$	17		$	18		$	―		$	1,719	Restricted receivables of variable interest entities		$	637	$	534	$	15		$	16		$	-1		$	1,201
	Other			―			―			―			10			89			2			101	Other			―		―		4			133			2			139
	Investments and Other Assets																						Investments and Other Assets
	Other			―			―			―			51			29			―			80	Other			―		―		62			14			2			78
	Property, Plant and Equipment																						Property, Plant and Equipment
	Property, plant and equipment, cost^(c)			―			―			―			―			1,662			18			1,680	Property, plant and equipment, cost^(b)			―		―		―			1,543			15			1,558
	Accumulated depreciation and amortization			―			―			―			―			-170			-5			-175	Accumulated depreciation and amortization			―		―		―			-98			-5			-103
	Regulatory Assets and Deferred Debits																						Regulatory Assets and Deferred Debits
	Other			1			1			―			―			34			―			36	Other			―		―		―			40			―			40
	Total assets			674			417			595			78			1,662			15			3,441	Total assets			637		534		81			1,648			13			2,913
	LIABILITIES AND EQUITY																						LIABILITIES AND EQUITY
	Current Liabilities																						Current Liabilities
	Accounts payable			―			―			―			―			2			―			2	Accounts payable			―		―		―			1			―			1
	Taxes accrued			―			―			―			―			10			―			10	Notes payable and commercial paper			―		312		―			―			―			312
	Current maturities of long-term debt			―			―			―			14			66			―			80	Taxes accrued			―		―		―			62			―			62
	Other			―			―			―			10			17			―			27	Current maturities of long-term debt			―		―		13			459			―			472
	Long-term Debt^(d)			400			300			325			34			907			―			1,966	Other			―		―		4			25			―			29
	Deferred Credits and Other Liabilities																						Long-term Debt^(c)			300		―		48			504			―			852
	Other			1			―			―			13			333			―			347	Deferred Credits and Other Liabilities
	Total liabilities			401			300			325			71			1,335			―			2,432	Deferred income taxes			―		―		―			154			―			154
	Net assets of consolidated variable interest entities		$	273		$	117		$	270		$	7		$	327		$	15		$	1,009	Asset retirement obligation			―		―		―			23			―			23
																							Other			―		―		10			39			―			49
	(a)	DERF is consolidated by Duke Energy Carolinas and Duke Energy.																					Total liabilities			300		312		75			1,267			―			1,954
	(b)	DEPR is consolidated by Duke Energy Progress and Duke Energy.																					Net assets of consolidated variable interest entities		$	337	$	222	$	6		$	381		$	13		$	959
	(c)	Restricted as collateral for non-recourse debt of VIEs.
	(d)	Non-recourse to the general assets of Duke Energy.																					(a)	DERF is consolidated by Duke Energy Carolinas and Duke Energy.
																							(b)	Restricted as collateral for non-recourse debt of VIEs.
																							(c)	Non-recourse to the general assets of Duke Energy.

Schedule Of Non-Consolidated VIEs	'																						'

			31-Dec-13																						31-Dec-12
			Duke Energy																						Duke Energy
	(in millions)		Renewables			Other			Total			Duke Energy Ohio^(a)			Duke Energy Indiana^(b)								(in millions)		DukeNet		Renewables		FPC Capital I Trust^(c)		Other			Total			Duke Energy Ohio^(a)			Duke Energy Indiana^(b)
	Receivables		$	―		$	―		$	―		$	114		$	143							Receivables		$	―	$	―	$	―	$	―		$	―		$	97		$	116
	Investments in equity method unconsolidated affiliates			153			60			213			―			―							Investments in equity method unconsolidated affiliates			118		147		―		27			292			―			―
	Intangibles			―			96			96			96			―							Intangibles			―		―		―		104			104			104			―
	Investments and other assets			―			4			4			―			―							Investments and other assets			―		―		9		2			11			―
	Total assets			153			160			313			210			143							Total assets			118		147		9		133			407			201			116
	Other current liabilities			―			3			3			―			―							Other current liabilities			―		―		―		3			3			―			―
	Deferred credits and other liabilities			―			15			15			―			―							Deferred credits and other liabilities			―		―		319		17			336			―			―
	Total liabilities			―			18			18			―			―							Total liabilities			―		―		319		20			339			―			―
	Net assets		$	153		$	142		$	295		$	210		$	143							Net assets (liabilities)		$	118	$	147	$	-310	$	113		$	68		$	201		$	116

	(a)	Reflects OVEC and retained interest in CRC.																					(a)	Reflects OVEC and retained interest in CRC.
	(b)	Reflects retained interest in CRC.																					(b)	Reflects retained interest in CRC.
																							(c)	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]	'																						'
CRC Fair Value Assumptions	'																						'
	Key assumptions used in estimating the fair value in 2013 and 2012 is 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	%

CRC Receivables Sold	'																						'
	The following table shows the gross and net receivables sold.

			Duke Energy Ohio						Duke Energy Indiana
			December 31,						December 31,
	(in millions)			2013		2012			2013			2012
	Receivables sold		$	290		$	282		$	340		$	289
	Less: Retained interests			114			97			143			116
	Net receivables sold		$	176		$	185		$	197		$	173

CRC Sales and Cash Flows	'																						'
	The following tables show sales and cash flows related to receivables sold.

				Duke Energy Ohio									Duke Energy Indiana
				Years Ended December 31,									Years Ended December 31,
	(in millions)			2013			2012			2011			2013			2012			2011
	Sales
	Receivables sold			$	2,251		$	2,154		$	2,390		$	2,985		$	2,773		$	2,658
	Loss recognized on sale				12			13			21			11			12			16
	Cash Flows
	Cash proceeds from receivables sold				2,220			2,172			2,474			2,944			2,784			2,674
	Collection fees received				1			1			1			1			1			1
	Return received on retained interests				5			5			12			6			7			13

Duke Energy Indiana [Member]	'																						'
Variable Interest Entity [Line Items]	'																						'
CRC Fair Value Assumptions	'																						'
	Key assumptions used in estimating the fair value in 2013 and 2012 is 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	%

CRC Receivables Sold	'																						'
	The following table shows the gross and net receivables sold.

			Duke Energy Ohio						Duke Energy Indiana
			December 31,						December 31,
	(in millions)			2013		2012			2013			2012
	Receivables sold		$	290		$	282		$	340		$	289
	Less: Retained interests			114			97			143			116
	Net receivables sold		$	176		$	185		$	197		$	173

CRC Sales and Cash Flows	'																						'
	The following tables show sales and cash flows related to receivables sold.

				Duke Energy Ohio									Duke Energy Indiana
				Years Ended December 31,									Years Ended December 31,
	(in millions)			2013			2012			2011			2013			2012			2011
	Sales
	Receivables sold			$	2,251		$	2,154		$	2,390		$	2,985		$	2,773		$	2,658
	Loss recognized on sale				12			13			21			11			12			16
	Cash Flows
	Cash proceeds from receivables sold				2,220			2,172			2,474			2,944			2,784			2,674
	Collection fees received				1			1			1			1			1			1
	Return received on retained interests				5			5			12			6			7			13

Common_Stock_Tables

Common Stock (Tables)	12 Months Ended
Common Stock (Tables)	Dec. 31, 2013							Dec. 31, 2012						Dec. 31, 2011
Earnings Per Share [Line Items]	'							'						'
Schedule Of Earnings Per Share	'							'						'
	(In millions, except per-share amounts)	Income		Average Shares		EPS		2012						2011
	2013							Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic	$	1,727	574	$	3.01	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	1,702	444	$	3.83
	Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	2,640		706	$	3.74	Effect of dilutive securities:
								Stock options, performance and restricted stock			1
								Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — diluted	$	1,727	575	$	3.01

Severance_Tables

Severance (Tables)	12 Months Ended
Severance (Tables)	Dec. 31, 2013
Restructuring Cost and Reserve [Line Items]	'
Schedule of Severance Liability	'

	(in millions)			Balance at December 31, 2012			Provision / Adjustments		Cash Reductions		Balance at December 31, 2013
	Duke Energy			$	135		$	52	$	-123	$	64
	Duke Energy Carolinas				12			6		-13		5
	Progress Energy				43			49		-48		44
	Duke Energy Progress				23			8		-20		11
	Duke Energy Florida				6			31		-13		24

Schedule of Severance Expense	'
	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 Consolidated Statements of Operations. The Duke Energy Registrants recorded insignificant amounts for severance expense during 2011 for past and ongoing severance plans.

			Years Ended December 31,
	(in millions)		2013			2012
	Duke Energy^(a)		$	34		$	201
	Duke Energy Carolinas			8			63
	Progress Energy			19			82
	Duke Energy Progress			14			55
	Duke Energy Florida			5			27
	Duke Energy Ohio			2			21
	Duke Energy Indiana			2			18

	(a)	Includes $5 million and $14 million of accelerated stock award expense and $2 million and $19 million of COBRA and healthcare reimbursement expenses for 2013 and 2012, respectively.

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
Stock-Based Compensation (Tables)	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule Of Total Stock-Based Compensation Expense, net of tax	'

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Duke Energy		$	52		$	48		$	32
	Duke Energy Carolinas			13			12			17
	Progress Energy			23			25			20
	Duke Energy Progress			14			16			12
	Duke Energy Florida			9			9			8
	Duke Energy Ohio			4			4			6
	Duke Energy Indiana			4			4			4

Schedule Of Stock-Based Compensation Expense	'

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Stock options		$	2		$	2		$	2
	Restricted stock unit awards			49			43			27
	Performance awards			34			33			23
	Pretax stock-based compensation cost		$	85		$	78		$	52
	Tax benefit associated with stock-based compensation expense		$	33		$	30		$	20
	Stock-based compensation costs capitalized			3			2			2

Schedule of Share-based Compensation, Stock Options, Activity	'
	STOCK OPTIONS

	The following table summarizes information about stock options outstanding.

			Options (in thousands)			Weighted-Average Exercise Price			Weighted-Average Remaining Life		Aggregate Intrinsic Value (in millions)
	Outstanding at December 31, 2012			1,654		$	51
	Granted			310			69
	Exercised			-1,162			48
	Forfeited or expired			-9			41
	Outstanding at December 31, 2013			793			61			7y, 3m	$	6
	Exercisable at December 31, 2013			137			46			1y, 5m		3
	Options expected to vest			656			64			8y, 5m		3

Schedule of Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period, Exercises	'
			Years Ended December 31,
	(in millions)		2013			2012			2011
	Intrinsic value of options exercised		$	26		$	17		$	26
	Tax benefit related to options exercised			10			7			10
	Cash received from options exercised			9			21			74
	Stock options granted (in thousands)			310			340			358

Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	'
	The following assumptions were used to determine the grant date fair value of stock options granted in 2013.

	Risk-free interest rate^(a)			1	%
	Expected dividend yield^(b)			4.7	%
	Expected life^(c)			6 years
	Expected volatility^(d)			18.1	%

	(a)	The risk-free rate is based upon the average of five-year and seven-year U.S. Treasury Constant Maturity rates as of the grant date.
	(b)	The expected dividend yield is based upon the most recent annualized dividend and the one-year average closing stock price.
	(c)	The expected life of options is derived from the simplified method approach.
	(d)	Volatility is based equally between historical and implied volatility. Historic volatility is based on Duke Energy's historical volatility over the expected life using daily stock prices. Implied volatility is the average for all option contracts with a term greater than six months using the strike price closest to the stock price on the valuation date.

Schedule of Share-based Compensation, Restricted Stock Units Awarded Activity	'

			Years Ended December 31,
			2013			2012			2011
	Shares awarded (in thousands)			612			443			636
	Fair value (in millions)^(a)		$	42		$	28		$	34

	(a)	Based on the market price of Duke Energy's common stock at the grant date.

Schedule of Share-based Compensation, Restricted Stock Units Award Activity	'
	The following table summarizes information about restricted stock unit awards outstanding.

				Shares (in thousands)			Weighted-Average Per Share Grant Date Fair Value
	Outstanding at December 31, 2012				1,607		$	64
	Granted				612			69
	Vested				-794			63
	Forfeited				-25			68
	Outstanding at December 31, 2013				1,400			66
	Restricted stock unit awards expected to vest				1,365			66

Schedule of Performance Awards	'

			Years Ended December 31,
			2013			2012			2011
	Shares awarded (in thousands)			633			352			432
	Fair value (in millions)		$	28		$	19		$	20

Schedule of Nonvested Performance-based Units Activity	'
	The following table summarizes information about stock-based performance awards outstanding at the maximum level.

			Shares (in thousands)			Weighted-Average Per Share Grant Date Fair Value
	Outstanding at December 31, 2012			2,346		$	47
	Granted			633			45
	Vested			-858			49
	Forfeited			-299			46
	Outstanding at December 31, 2013			1,822			46
	Stock-based performance awards expected to vest			1,646			47

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
Employee Benefit Plans (Tables)	Dec. 31, 2013																			Dec. 31, 2012																	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Pension Plan Contributions	'																			'																	'

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Anticipated Contributions:
	2014		$	143		$	42		$	51		$	21	$	21	$	4	$	9
	Contributions Made:
	2013		$	250		$	—		$	250		$	63	$	133	$	—	$	—
	2012			304			—			346			141		128		—		—
	2011			200			33			334			217		112		48		52

Employee Savings Plan Matching Contributions	'																			'																	'
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Years ended December 31,
		2013	$	134		$	45		$	45		$	25	$	14	$	3	$	7
		2012		107			37			45			24		15		4		6
		2011		86			37			44			23		14		4		8

Qualified Pension Plans [Member]	'																			'																	'
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Components of Net Periodic Pension Costs	'																			'																	'
	Components of Net Periodic Pension Costs																					Year Ended December 31, 2012																Year Ended December 31, 2011
																				(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
			Year Ended December 31, 2013																	Service cost		$	122		$	35	$	63	$	25	$	30	$	6	$	9	Service cost	$	96	$	37	$	51	$	20	$	24	$	7	$	11
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana		Interest cost on projected benefit obligation			307			90		127		58		56		31		30	Interest cost on projected benefit obligation		232		85		132		61		57		32		30
	Service cost		$	167		$	49		$	60		$	22	$	30	$	6	$	11	Expected return on plan assets			-472			-146		-188		-96		-81		-45		-46	Expected return on plan assets		-384		-150		-182		-91		-78		-44		-45
	Interest cost on projected benefit obligation			320			80			116			50		53		21		28	Amortization of actuarial loss			144			45		93		37		48		10		15	Amortization of actuarial loss		77		37		66		25		33		7		14
	Expected return on plan assets			-549			-148			-199			-94		-87		-31		-46	Amortization of prior service cost (credit)			10			1		9		8		-1		1		1	Amortization of prior service cost		6		1		7		6		―		1		2
	Amortization of actuarial loss			244			60			101			46		49		13		24	Other			6			2		2		1		1		―		―	Other		18		7		―		―		―		2		2
	Amortization of prior service (credit) cost			-11			-6			-4			-1		-2		―		1	Net periodic pension costs^(a)(b)		$	117		$	27	$	106	$	33	$	53	$	3	$	9	Net periodic pension costs^(a)(b)	$	45	$	17	$	74	$	21	$	36	$	5	$	14
	Other			7			2			2			1		1		―		1
	Net periodic pension costs^(a)(b)		$	178		$	37		$	76		$	24	$	44	$	9	$	19

Amounts Recognized in AOCI and Regulatory Assets and Liabilities	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 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
	Regulatory assets, net decrease		$	-788		$	-205		$	-253		$	-109	$	-146	$	-96	$	-99	Regulatory assets, net increase (decrease)		$	976		$	-111	$	-76	$	-89	$	23	$	22	$	17
	Accumulated other comprehensive (income) loss																			Accumulated other comprehensive (income) loss
	Deferred income tax benefit		$	18		$	―		$	―		$	―	$	―	$	―	$	―	Deferred income tax benefit		$	14		$	―	$	―	$	―	$	―	$	15	$	―
	Actuarial gains arising during the year			-33			―			-2			―		―		―		―	Reclassification of actuarial losses to an affiliate			―			―		―		―		―		-48		―
	Prior year service credit arising during the year			-1			―			―			―		―		―		―	Actuarial (gains) losses arising during the year			-2			―		3		―		―		―		―
	Amortization of prior year actuarial losses			-15			―			-3			―		―		―		―	Prior year service credit arising during the year			-7			―		―		―		―		―		―
	Reclassification of actuarial losses to regulatory assets			3			―			―			―		―		―		―	Amortization of prior year actuarial losses			-13			―		-2		―		―		-3		―
	Net amount recognized in accumulated other comprehensive income		$	-28		$	―		$	-5		$	―	$	―	$	―	$	―	Reclassification of actuarial losses to regulatory assets			-20			―		―		―		―		-1		―
																				Amortization of prior year service cost			-1			―		-1		―		―		-1		―
																				Net amount recognized in accumulated other comprehensive income		$	-29		$	―	$	―	$	―	$	―	$	-38	$	―

Reconciliation of Funded Status to Net Amount Recognized	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 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
	Change in Projected Benefit Obligation																			Change in Projected Benefit Obligation
	Obligation at prior measurement date		$	8,030		$	2,028		$	2,868		$	1,264	$	1,309	$	527	$	684	Obligation at prior measurement date		$	4,880		$	1,831	$	2,729	$	1,263	$	1,179	$	627	$	613
	Service cost			167			49			60			22		30		6		11	Obligation assumed from acquisition			2,850			―		―		―		―		―		―
	Interest cost			320			80			116			50		53		21		28	Service cost			122			35		63		25		30		6		9
	Actuarial gains			-399			-73			-118			-26		-75		-71		-56	Interest cost			307			90		127		58		56		31		30
	Transfers			―			-26			-7			-45		-17		-2		-2	Actuarial losses			489			73		166		34		120		68		76
	Plan amendments			-41			-13			-19			-8		-7		―		―	Transfers			―			176		―		―		―		-167		―
	Benefits paid			-567			-170			-161			-85		-60		-39		-33	Plan amendments			-170			-52		-64		-43		-10		―		-1
	Obligation at measurement date		$	7,510		$	1,875		$	2,739		$	1,172	$	1,233	$	442	$	632	Benefits paid			-448			-125		-153		-73		-66		-38		-43
	Accumulated Benefit Obligation at measurement date		$	7,361		$	1,875		$	2,698		$	1,172	$	1,192	$	429	$	608	Obligation at measurement date		$	8,030		$	2,028	$	2,868	$	1,264	$	1,309	$	527	$	684
	Change in Fair Value of Plan Assets																			Accumulated Benefit Obligation at measurement date		$	7,843		$	2,028	$	2,820	$	1,264	$	1,261	$	501	$	653
	Plan assets at prior measurement date		$	7,754		$	2,151		$	2,647		$	1,289	$	1,150	$	446	$	627	Change in Fair Value of Plan Assets
	Actual return on plan assets			705			207			215			108		93		43		62	Plan assets at prior measurement date		$	4,741		$	1,820	$	2,191	$	1,091	$	969	$	565	$	582
	Benefits paid			-567			-170			-161			-85		-60		-39		-33	Assets received from acquisition			2,285			―		―		―		―		―		―
	Transfers			―			-26			-7			-45		-17		-2		-2	Actual return on plan assets			872			280		263		130		119		86		88
	Employer contributions			250			―			250			63		133		―		―	Benefits paid			-448			-125		-153		-73		-66		-38		-43
	Plan assets at measurement date		$	8,142		$	2,162		$	2,944		$	1,330	$	1,299	$	448	$	654	Transfers			―			176		―		―		―		-167		―
	Funded status of plan		$	632		$	287		$	205		$	158	$	66	$	6	$	22	Employer contributions			304			―		346		141		128		―		―
																				Plan assets at measurement date		$	7,754		$	2,151	$	2,647	$	1,289	$	1,150	$	446	$	627
																				Funded status of plan		$	-276		$	123	$	-221	$	25	$	-159	$	-81	$	-57

Amounts Recognized in the Consolidated Balance Sheet	'																			'																	'
			31-Dec-13																			31-Dec-12
	(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
	Prefunded pension^(a)		$	632		$	287		$	230		$	158	$	66	$	2	$	75	Prefunded pension^(a)		$	163		$	123	$	―	$	25	$	―	$	―	$	―
	Noncurrent pension liability		$	―		$	―		$	25		$	―	$	―	$	-4	$	53	Noncurrent pension liability		$	439		$	―	$	221	$	―	$	159	$	81	$	57
	Net asset recognized		$	632		$	287		$	205		$	158	$	66	$	6	$	22	Net asset (liability) recognized		$	-276		$	123	$	-221	$	25	$	-159	$	-81	$	-57
	Regulatory assets		$	1,599		$	377		$	826		$	363	$	395	$	48	$	147	Regulatory assets		$	2,387		$	582	$	1,079	$	472	$	541	$	144	$	246
	Accumulated other comprehensive (income) loss																			Accumulated other comprehensive (income) loss
	Deferred income tax asset		$	-41		$	―		$	-9		$	―	$	―	$	―	$	―	Deferred income tax asset		$	-59		$	―	$	-9	$	―	$	―	$	―	$	―
	Prior service credit			-5			―			―			―		―		―		―	Prior service credit			-4			―		―		―		―		―		―
	Net actuarial loss			121			―			21			―		―		―		―	Net actuarial loss			166			―		26		―		―		―		―
	Net amounts recognized in accumulated other comprehensive loss^(b)		$	75		$	―		$	12		$	―	$	―	$	―	$	―	Net amounts recognized in accumulated other comprehensive loss^(b)		$	103		$	―	$	17	$	―	$	―	$	―	$	―
	Amounts to be recognized in net periodic pension expense in the next year
	Unrecognized net actuarial loss		$	149		$	35		$	71		$	33	$	32	$	4	$	7
	Unrecognized prior service credit			-15			-8			-4			-2		-1		―		―

Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets	'																			'																	'
	Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets

	As of December 31, 2013, no qualified pension plans had an accumulated benefit obligation in excess of plan assets.

			31-Dec-12
	(in millions)		Duke Energy			Progress Energy			Duke Energy Florida			Duke Energy Ohio		Duke Energy Indiana
	Projected benefit obligation		$	5,396		$	2,868		$	1,309		$	527	$	684
	Accumulated benefit obligation			5,201			2,820			1,261			501		653
	Fair value of plan assets			4,957			2,647			1,150			446		627

Assumptions Used for Pension Benefits Accounting	'																			'																	'

			Duke Energy									Progress Energy
			December 31,									December 31,
			2013			2012			2011			2013		2012		2011
	Benefit Obligations
	Discount rate		4.7	%		4.1	%		5.1	%		4.7	%	4.1	%	4.75	%
	Salary increase		4.4	%		4.3	%		4.4	%		4	%	4	%	4	%
	Net Periodic Benefit Cost
	Discount rate		4.1	%		4.60-5.10	%		5	%		4.1	%	4.60-4.75	%	5.55	%
	Salary increase		4.3	%		4.4	%		4.1	%		4	%	4	%	4.5	%
	Expected long-term rate of return on plan assets		7.75	%		8	%		8.25	%		7.75	%	8.00-8.25	%	8.5	%

Expected Benefit Payments	'																			'																	'
	Expected Benefit Payments

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Years ending December 31,
	2014		$	667		$	224		$	190		$	98	$	68	$	36	$	47
	2015			643			218			185			92		71		35		45
	2016			640			212			190			93		74		34		46
	2017			633			205			191			91		77		34		44
	2018			623			196			194			91		80		34		46
	2019 - 2023			2,933			807			969			422		430		171		227

Non-Qualified Pension Plans [Member]	'																			'																	'
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Components of Net Periodic Pension Costs	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 2012																Year Ended December 31, 2011
	(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		$	3		$	―		$	1		$	1	$	―	$	―	$	―	Service cost		$	2		$	―	$	2	$	1	$	―	$	―	$	―	Service cost	$	1	$	―	$	2	$	1	$	―	$	―	$	―
	Interest cost on projected benefit obligation			13			1			7			1		1		―		―	Interest cost on projected benefit obligation			12			1		8		1		2		―		―	Interest cost on projected benefit obligation		8		1		9		2		2		―		―
	Amortization of actuarial loss			5			―			3			1		1		―		―	Amortization of actuarial loss			4			―		5		1		―		―		―	Amortization of actuarial loss		―		―		3		―		1		―		―
	Amortization of prior service credit			-1			―			-1			―		―		―		―	Amortization of prior service cost (credit)			1			―		-1		―		―		―		―	Amortization of prior service cost		2		―		―		―		―		―		―
	Net periodic pension costs		$	20		$	1		$	10		$	3	$	2	$	―	$	―	Net periodic pension costs		$	19		$	1	$	14	$	3	$	2	$	―	$	―	Net periodic pension costs	$	11	$	1	$	14	$	3	$	3	$	―	$	―

Amounts Recognized in AOCI and Regulatory Assets and Liabilities	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 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
	Regulatory assets, net (decrease) increase		$	-14		$	1		$	-16		$	-4	$	-3	$	―	$	-2	Regulatory assets, net increase (decrease)		$	34		$	―	$	-6	$	-2	$	1	$	―	$	―
	Regulatory liabilities, net increase		$	5		$	―		$	―		$	―	$	―	$	―	$	―	Regulatory liabilities, net increase		$	-8		$	―	$	―	$	―	$	―	$	―	$	―
	Accumulated other comprehensive (income) loss																			Accumulated other comprehensive (income) loss
	Deferred income tax benefit		$	―		$	―		$	1		$	―	$	―	$	―	$	―	Deferred income tax benefit		$	―		$	―	$	-1	$	―	$	―	$	―	$	―
	Actuarial losses (gains) arising during the year			2			―			-5			―		―		―		―	Actuarial (gains) losses arising during the year			-2			―		3		―		―		―		―
	Prior year service credit arising during the year			-1			―			―			―		―		―		―	Net amount recognized in accumulated other comprehensive (income) loss		$	-2		$	―	$	2	$	―	$	―	$	―	$	―
	Net amount recognized in accumulated other comprehensive loss (income)		$	1		$	―		$	-4		$	―	$	―	$	―	$	―

Reconciliation of Funded Status to Net Amount Recognized	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 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
	Change in Projected Benefit Obligation																			Change in Projected Benefit Obligation
	Obligation at prior measurement date		$	335		$	16		$	176		$	38	$	45	$	4	$	5	Obligation at prior measurement date		$	160		$	18	$	177	$	39	$	44	$	4	$	5
	Service cost			3			―			1			1		―		―		―	Obligation assumed from acquisition			172			―		―		―		―		―		―
	Interest cost			13			1			7			1		1		―		―	Service cost			2			―		2		1		―		―		―
	Actuarial losses			-15			1			-11			-3		-3		-1		―	Interest cost			12			1		8		1		2		―		―
	Settlements			-5			―			―			―		―		―		―	Actuarial losses			18			―		11		3		3		―		―
	Plan amendments			-1			―			―			―		―		―		―	Plan amendments			-5			―		-12		-4		-2		―		―
	Transfers			―			―			-21			―		―		―		―	Transfers			―			1		―		―		―		―		―
	Benefits paid			-26			-3			-12			-3		-4		―		―	Benefits paid			-24			-4		-10		-2		-2		―		―
	Obligation at measurement date		$	304		$	15		$	140		$	34	$	39	$	3	$	5	Obligation at measurement date		$	335		$	16	$	176	$	38	$	45	$	4	$	5
	Accumulated Benefit Obligation at measurement date		$	302		$	15		$	140		$	34	$	39	$	3	$	5	Accumulated Benefit Obligation at measurement date		$	332		$	16	$	175	$	36	$	44	$	4	$	5
	Change in Fair Value of Plan Assets																			Change in Fair Value of Plan Assets
	Plan assets at prior measurement date		$	―		$	―		$	―		$	―	$	―	$	―	$	―	Plan assets at prior measurement date		$	―		$	―	$	―	$	―	$	―	$	―	$	―
	Benefits paid			-26			-3			-12			-3		-4		―		―	Benefits paid			-24			-4		-10		-2		-3		―		―
	Employer contributions			26			3			12			3		4		―		―	Employer contributions			24			4		10		2		3		―		―
	Plan assets at measurement date		$	―		$	―		$	―		$	―	$	―	$	―	$	―	Plan assets at measurement date		$	―		$	―	$	―	$	―	$	―	$	―	$	―

Amounts Recognized in the Consolidated Balance Sheet	'																			'																	'
			31-Dec-13																			31-Dec-12
	(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
	Current pension liability^(a)		$	30		$	2		$	11		$	2	$	3	$	―	$	―	Current pension liability^(a)		$	30		$	3	$	11	$	2	$	3	$	―	$	―
	Noncurrent pension liability			274			13			129			32		36		3		5	Noncurrent pension liability			305			13		165		36		42		4		5
	Total accrued pension liability		$	304		$	15		$	140		$	34	$	39	$	3	$	5	Total accrued pension liability		$	335		$	16	$	176	$	38	$	45	$	4	$	5
	Regulatory assets		$	45		$	4		$	18		$	3	$	6	$	―	$	―	Regulatory assets		$	59		$	3	$	34	$	7	$	9	$	―	$	2
	Regulatory liabilities		$	7		$	―		$	―		$	―	$	―	$	―	$	―	Regulatory liabilities		$	2		$	―	$	―	$	―	$	―	$	―	$	―
	Accumulated other comprehensive (income) loss																			Accumulated other comprehensive (income) loss
	Deferred income tax asset		$	―		$	―		$	-3		$	―	$	―	$	―	$	―	Deferred income tax asset		$	―		$	―	$	-4	$	―	$	―	$	―	$	―
	Prior service credit			-1			―			―			―		―		―		―	Net actuarial (gain) loss			-1			―		12		―		―		―		―
	Net actuarial loss			1			―			7			―		―		―		―	Net amounts recognized in accumulated other comprehensive (income) loss		$	-1		$	―	$	8	$	―	$	―	$	―	$	―
	Net amounts recognized in accumulated other comprehensive loss		$	―		$	―		$	4		$	―	$	―	$	―	$	―
	Amounts to be recognized in net periodic pension expense in the next year
	Unrecognized net actuarial loss		$	5		$	―		$	2		$	1	$	―	$	―	$	―
	Unrecognized prior service credit			-1			―			-1			-1		―		―		―

Information for Plans with Accumulated Benefit Obligation in Excess of Plan Assets	'																			'																	'
			31-Dec-13																			31-Dec-12
	(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
	Projected benefit obligation		$	304		$	15		$	140		$	34	$	39	$	3	$	5	Projected benefit obligation		$	335		$	16	$	176	$	38	$	45	$	4	$	5
	Accumulated benefit obligation			302			15			140			34		39		3		5	Accumulated benefit obligation			332			16		175		36		44		4		5

Assumptions Used for Pension Benefits Accounting	'																			'																	'

			Duke Energy									Progress Energy
			December 31,									December 31,
			2013			2012			2011			2013		2012		2011
	Benefit Obligations
	Discount rate		4.7	%		4.1	%		5.1	%		4.7	%	4.1	%	4.8	%
	Salary increase		4.4	%		4.3	%		4.4	%		―	%	―	%	5.25	%
	Net Periodic Benefit Cost
	Discount rate		4.1	%		4.60-5.10	%		5	%		4.1	%	4.60-4.80	%	5.6	%
	Salary increase		4.3	%		4.4	%		4.1	%		―	%	―	%	5.25	%

Expected Benefit Payments	'																			'																	'
	Expected Benefit Payments

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Years ending December 31,
	2014		$	31		$	3		$	11		$	2	$	3	$	―	$	―
	2015			28			2			11			2		3		―		―
	2016			26			2			11			2		3		―		―
	2017			27			2			11			2		3		―		―
	2018			24			2			11			2		3		―		―
	2019 - 2023			112			6			52			13		15		1		2

Other Post-Retirement Benefit Plans [Member]	'																			'																	'
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Components of Net Periodic Pension Costs	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 2012																Year Ended December 31, 2011
	(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		$	24		$	2		$	18		$	9	$	7	$	1	$	1	Service cost		$	16		$	2	$	17	$	8	$	7	$	1	$	1	Service cost	$	7	$	2	$	11	$	5	$	5	$	1	$	1
	Interest cost on accumulated post-retirement benefit obligation			68			13			41			22		16		2		5	Interest cost on accumulated post-retirement benefit obligation			56			15		43		23		18		3		6	Interest cost on accumulated post-retirement benefit obligation		35		16		41		20		18		3		7
	Expected return on plan assets			-14			-11			―			―		―		-1		-1	Expected return on plan assets			-17			-10		-2		―		-2		-1		-1	Expected return on plan assets		-15		-10		-2		―		-2		-1		-1
	Amortization of actuarial loss (gain)			52			3			57			34		16		-1		1	Amortization of actuarial loss (gain)			14			3		35		20		12		-2		―	Amortization of actuarial (gain) loss		-3		2		12		5		7		-2		2
	Amortization of prior service credit			-41			-7			-30			-20		-6		-1		―	Amortization of prior service credit			-8			-5		―		―		―		-1		―	Amortization of prior service credit		-8		-5		―		―		―		-1		―
	Net periodic post-retirement benefit costs^(a)(b)		$	89		$	―		$	86		$	45	$	33	$	―	$	6	Amortization of net transition liability			10			7		4		―		3		―		―	Amortization of net transition liability		10		9		5		1		4		―		―
																				Special termination benefit cost			9			1		5		2		1		―		―	Net periodic post-retirement benefit costs^(a)(b)	$	26	$	14	$	67	$	31	$	32	$	―	$	9
																				Net periodic post-retirement benefit costs^(a)(b)		$	80		$	13	$	102	$	53	$	39	$	―	$	6

Amounts Recognized in AOCI and Regulatory Assets and Liabilities	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 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
	Regulatory assets, net (decrease) increase		$	-683		$	-51		$	-634		$	-388	$	-166	$	―	$	-6	Regulatory assets, net increase (decrease)		$	484		$	-20	$	228	$	170	$	28	$	―	$	-6
	Regulatory liabilities, net increase (decrease)		$	30		$	―		$	―		$	―	$	―	$	3	$	9	Regulatory liabilities, net decrease		$	-6		$	―	$	―	$	―	$	―	$	-1	$	-2
	Accumulated other comprehensive (income) loss																			Accumulated other comprehensive (income) loss
	Deferred income tax benefit		$	2		$	―		$	―		$	―	$	―	$	―	$	―	Deferred income tax expense		$	-2		$	―	$	―	$	―	$	―	$	-4	$	―
	Actuarial gains arising during the year			-4			―			―			―		―		―		―	Reclassification of actuarial losses to an affiliate			―			―		―		―		―		6		―
	Prior year service credit arising during the year			-3			―			―			―		―		―		―	Actuarial losses arising during the year			―			―		―		―		―		2		―
	Amortization of prior year actuarial loss			1			―			―			―		―		―		―	Prior year service cost arising during the year			―			―		―		―		―		1		―
	Net amount recognized in accumulated other comprehensive income		$	-4		$	―		$	―		$	―	$	―	$	―	$	―	Amortization of prior year actuarial loss			―			―		―		―		―		1		―
																				Reclassification of actuarial gains to regulatory liabilities			4			―		―		―		―		―		―
																				Net amount recognized in accumulated other comprehensive loss		$	2		$	―	$	―	$	―	$	―	$	6	$	―

Reconciliation of Funded Status to Net Amount Recognized	'																			'																	'
			Year Ended December 31, 2013																			Year Ended December 31, 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
	Change in Projected Benefit Obligation																			Change in Projected Benefit Obligation
	Accumulated post-retirement benefit obligation at prior measurement date		$	1,794		$	316		$	1,128		$	612	$	413	$	48	$	136	Accumulated post-retirement benefit obligation at prior measurement date		$	667		$	312	$	841	$	407	$	368	$	61	$	135
	Service cost			24			2			18			9		7		1		1	Obligation assumed from acquisition			977			―		―		―		―		―		―
	Interest cost			68			13			41			22		16		2		5	Service cost			16			2		17		8		7		1		1
	Plan participants' contributions			47			15			14			6		7		3		3	Interest cost			56			15		43		23		18		3		6
	Actuarial gains			-227			-32			-156			-73		-70		-6		-12	Plan participants' contributions			41			18		13		5		7		4		8
	Transfers			―			―			-1			-8		―		―		―	Actuarial gains			198			28		291		205		49		3		-2
	Benefits paid			-132			-36			-60			-26		-31		-6		-14	Transfers			―			9		―		―		―		-16		―
	Plan amendments			-476			-16			-455			-311		-91		―		-3	Benefits paid			-105			-38		-61		-24		-33		-8		-13
	Accrued retiree drug subsidy			8			3			4			2		2		―		2	Special termination benefit cost			9			1		5		2		1		―		―
	Accumulated post-retirement benefit obligation at measurement date		$	1,106		$	265		$	533		$	233	$	253	$	42	$	118	Plan amendments			-70			-33		-25		-16		-6		―		―
	Change in Fair Value of Plan Assets																			Accrued retiree drug subsidy			5			2		4		2		2		―		1
	Plan assets at prior measurement date		$	198		$	134		$	―		$	―	$	―	$	7	$	17	Accumulated post-retirement benefit obligation at measurement date		$	1,794		$	316	$	1,128	$	612	$	413	$	48	$	136
	Actual return on plan assets			18			13			―			―		―		2		2	Change in Fair Value of Plan Assets
	Benefits paid			-132			-36			-60			-26		-31		-6		-14	Plan assets at prior measurement date		$	181		$	120	$	37	$	―	$	37	$	9	$	14
	Transfers^(a)			―			-1			―			―		―		―		―	Actual return on plan assets			23			12		2		―		2		1		2
	Employer contributions			83			18			46			20		24		2		10	Benefits paid			-105			-38		-61		-24		-33		-8		-13
	Plan participants' contributions			47			15			14			6		7		3		3	Transfers^(a)			―			5		-39		―		-39		-3		―
	Plan assets at measurement date		$	214		$	143		$	―		$	―	$	―	$	8	$	18	Employer contributions			58			17		48		19		26		4		6
																				Plan participants' contributions			41			18		13		5		7		4		8
																				Plan assets at measurement date		$	198		$	134	$	―	$	―	$	―	$	7	$	17

																				(a)	Progress Energy and Duke Energy Florida amounts reflect assets that did not meet the definition of plan assets. These assets are included in Other within Investments and Other Assets on the Consolidated Balance Sheets.

Amounts Recognized in the Consolidated Balance Sheet	'																			'																	'
			31-Dec-13																			31-Dec-12
	(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
	Current post-retirement liability^(a)		$	39		$	―		$	36		$	17	$	16	$	2	$	―	Current post-retirement liability^(a)		$	50		$	―	$	47	$	23	$	20	$	2	$	―
	Noncurrent post-retirement liability			853			122			497			216		237		32		100	Noncurrent post-retirement liability			1,546			182		1,081		589		393		39		119
	Total accrued post-retirement liability		$	892		$	122		$	533		$	233	$	253	$	34	$	100	Total accrued post-retirement liability		$	1,596		$	182	$	1,128	$	612	$	413	$	41	$	119
	Regulatory assets		$	-162		$	-34		$	-129		$	-97	$	4	$	―	$	71	Regulatory assets		$	521		$	17	$	505	$	291	$	170	$	―	$	77
	Regulatory liabilities		$	131		$	―		$	―		$	―	$	―	$	21	$	77	Regulatory liabilities		$	101		$	―	$	―	$	―	$	―	$	18	$	68
	Accumulated other comprehensive (income) loss																			Accumulated other comprehensive (income) loss
	Deferred income tax liability		$	4		$	―		$	―		$	―	$	―	$	―	$	―	Deferred income tax liability		$	2		$	―	$	―	$	―	$	―	$	―	$	―
	Prior service credit			-5			―			―			―		―		―		―	Prior service credit			-3			―		―		―		―		―		―
	Net actuarial gain			-6			―			―			―		―		―		―	Net actuarial gain			-2			―		―		―		―		―		―
	Net amounts recognized in accumulated other comprehensive income		$	-7		$	―		$	―		$	―	$	―	$	―	$	―	Net amounts recognized in accumulated other comprehensive income		$	-3		$	―	$	―	$	―	$	―	$	―	$	―
	Amounts to be recognized in net periodic pension expense in the next year
	Unrecognized net actuarial loss (gain)		$	38		$	3		$	46			30	$	10	$	-2	$	-6
	Unrecognized prior service credit			-125			-10			-112			-73		-21		―		―

Assumptions Used for Pension Benefits Accounting	'																			'																	'

			Duke Energy									Progress Energy
			December 31,									December 31,
			2013			2012			2011			2013		2012		2011
	Benefit Obligations
	Discount rate		4.7	%		4.1	%		5.1	%		4.7	%	4.1	%	4.85	%
	Net Periodic Benefit Cost
	Discount rate		4.1	%		4.60-5.10	%		5	%		4.1	%	4.60-4.85	%	5.7	%
	Expected long-term rate of return on plan assets		7.75	%		5.20-8.00	%		5.36-8.25	%		―	%	N/A-5.00	%	5	%
	Assumed tax rate		35	%		35	%		35	%

Assumed Health Care Cost Trend Rate	'																			'																	'
	Assumed Health Care Cost Trend Rate

			December 31,
			2013			2012
	Health care cost trend rate assumed for next year		8.5	%		8.5	%
	Rate to which the cost trend is assumed to decline (the ultimate trend rate)		5	%		5	%
	Year that rate reaches ultimate trend		2021			2020

Sensitivity to Changes in Assumed Health Care Cost Trend Rates	'																			'																	'
	Sensitivity to Changes in Assumed Health Care Cost Trend Rates

			Year Ended December 31, 2013
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	1-Percentage Point Increase
	Effect on total service and interest costs		$	11		$	2		$	7		$	4	$	3	$	1	$	1
	Effect on post-retirement benefit obligation			42			10			20			9		10		2		4
	1-Percentage Point Decrease
	Effect on total service and interest costs			-9			-1			-6			-3		-2		—		-1
	Effect on post-retirement benefit obligation			-36			-9			-16			-7		-8		-1		-4

Expected Benefit Payments	'																			'																	'
	Expected Benefit Payments

	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
	Years ending December 31,
		2014	$	85		$	21		$	36		$	17	$	17	$	4	$	11
		2015		88			22			38			17		17		4		12
		2016		89			23			38			18		17		4		12
		2017		89			23			38			18		17		3		11
		2018		89			24			38			18		17		3		11
		2019 - 2023		413			109			180			81		84		17		47

Master Trust [Member]	'																			'																	'
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Fair Value and Allocation of Plan Assets	'																			'																	'
																						31-Dec-12
							Actual Allocation at December 31,													(in millions)		Total Fair Value			Level 1		Level 2		Level 3
			Target Allocation				2013			2012										Equity securities		$	2,993		$	1,415	$	1,575	$	3
	U.S. equity securities			10	%		10	%		28	%									Corporate debt securities			1,391			―		1,388		3
	Non-U.S. equity securities			8	%		8	%		15	%									Short-term investment funds			100			23		77		―
	Global equity securities			10	%		10	%		10	%									Partnership interests			141			―		―		141
	Global private equity securities			3	%		3	%		3	%									Hedge funds			97			―		97		―
	Debt securities			63	%		63	%		32	%									Real estate trusts			167			―		―		167
	Hedge funds			2	%		3	%		4	%									U.S. government securities			237			―		237		―
	Real estate and cash			2	%		1	%		4	%									Guarantees investment contracts			37			―		―		37
	Other global securities			2	%		2	%		4	%									Governments bonds - foreign			65			―		64		1
	Total			100	%		100	%		100	%									Cash			4			4		―		―
																				Asset backed securities			14			―		14		―
	Duke Energy Master Retirement Trust																			Net pending transactions and other investments			-16			-21		5		―
																				Total assets^(a)		$	5,230		$	1,421	$	3,457	$	352
	The following tables provide the fair value measurement amounts for the Duke Energy Master Retirement Trust qualified pension and other post-retirement assets.
																				(a)	Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana were allocated approximately 43 percent, 9 percent and 12 percent, respectively, of the Duke Energy Master Retirement Trust assets at December 31, 2012. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to Duke Energy Carolinas, Duke Energy Ohio and Duke Energy Indiana using these percentages.
			31-Dec-13
	(in millions)		Total Fair Value			Level 1			Level 2			Level 3
	Equity securities		$	2,877		$	1,801		$	1,022		$	54
	Corporate debt securities			2,604			―			2,601			3
	Short-term investment funds			1,158			254			904			―
	Partnership interests			307			―			―			307
	Hedge funds			164			―			111			53
	Real estate trusts			95			―			―			95
	U.S. government securities			927			―			927			―
	Guaranteed investment contracts			33			―			―			33
	Governments bonds - foreign			19			―			18			1
	Cash			58			58			―			―
	Government and commercial mortgage backed securities			7			―			7			―
	Net pending transactions and other investments			12			7			5			―
	Total assets^(a)		$	8,261		$	2,120		$	5,595		$	546

	(a)	Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana were allocated approximately 28 percent, 35 percent, 16 percent, 16 percent, 5 percent and 8 percent, respectively, of the Duke Energy Master Retirement Trust assets at December 31, 2013. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to the Subsidiary Registrants using these percentages.

Master Trust Level 3 Rollforward	'																			'																	'
	The following tables provide a reconciliation of beginning and ending balances of assets of master trusts measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3).

	(in millions)		2013			2012
	Balance at January 1		$	352		$	322
	Combination of trust assets			288			―
	Purchases, sales, issuances and settlements
	Purchases			25			21
	Sales			-152			-4
	Total gains (losses) and other			33			13
	Balance at December 31		$	546		$	352

Voluntary Employee Beneficiary Association [Member]	'																			'																	'
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Fair Value and Allocation of Plan Assets	'																			'																	'
																						31-Dec-12
							Actual Allocation at December 31,													(in millions)		Total Fair Value			Level 1		Level 2		Level 3
			Target Allocation				2013			2012										Cash and cash equivalents		$	22		$	―	$	22	$	―
	U.S. equity securities			30	%		29	%		23	%									Equity securities			12			―		12		―
	Debt securities			45	%		29	%		32	%									Debt securities			16			―		16		―
	Cash			25	%		42	%		45	%									Total assets		$	50		$	―	$	50	$	―
	Total			100	%		100	%		100	%

			31-Dec-13
	(in millions)		Total Fair Value			Level 1			Level 2			Level 3
	Cash and cash equivalents		$	21		$	―		$	21		$	―
	Equity securities			15			―			15			―
	Debt securities			15			―			15			―
	Total assets		$	51		$	―		$	51		$	―

Progress Energy [Member] \| Master Trust [Member]	'																			'																	'
Defined Benefit Plan Disclosure [Line Items]	'																			'																	'
Fair Value and Allocation of Plan Assets	'																			'																	'

																							Actual Allocation at December 31,
																							2012
																				U.S. equity securities			20	%
																				Non-U.S. equity securities			14	%
																				Global equity securities			8	%
																				Global private equity securities			10	%
																				Debt securities			35	%
																				Hedge funds			9	%
																				Real estate and cash			1	%
																				Other global securities			3	%
																				Total			100	%

																				Progress Energy Master Retirement Trust

																				The following table provides the fair value measurement amounts for the Progress Energy Master Retirement Trust qualified pension assets.

																						31-Dec-12
																				(in millions)		Total Fair Value			Level 1		Level 2		Level 3
																				Equity securities		$	1,094		$	361	$	733	$	―
																				Corporate debt securities			432			―		432		―
																				Partnership interests			154			―		―		154
																				Hedge funds			313			―		189		124
																				U.S. government securities			515			405		110		―
																				Governments bonds - foreign			6			―		6		―
																				Cash			160			113		47		―
																				Net pending transactions and other investments			16			―		6		10
																				Total assets^(a)		$	2,690		$	879	$	1,523	$	288

																				(a)	Duke Energy Progress and Duke Energy Florida were allocated approximately 48 percent and 44 percent, respectively, of the Progress Energy Master Trust assets at December 31, 2012. Accordingly, all Level 1, 2 and 3 amounts included in the table above are allocable to Duke Energy Progress and Duke Energy Florida using these percentages.

Master Trust Level 3 Rollforward	'																			'																	'
	The following tables provide a reconciliation of beginning and ending balances of Progress Trust assets measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3).

	(in millions)		2013			2012
	Balance at January 1		$	288		$	311
	Combination of trust assets			-288			―
	Purchases, sales, issuances and settlements
	Purchases			―			13
	Sales			―			-14
	Transfers in and/or out of level 3			―			-41
	Total gains (losses) and other			―			19
	Balance at December 31		$	―		$	288

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2013																							Dec. 31, 2012																							Dec. 31, 2011
Income Tax Disclosure [Line Items]	'																							'																							'
Schedule of Components of Income Tax Expense (Benefit)	'																							'																							'

			Year Ended December 31, 2013																							Year Ended December 31, 2012																							Year Ended December 31, 2011
	(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
	Current income taxes																							Current income taxes																							Current income taxes
	Federal		$	-123		$	49		$	-221		$	-70		$	-143		$	-21		$	-88		Federal		$	-46		$	-1		$	-88		$	-48		$	6		$	26		$	-27		Federal		$	-37		$	-122		$	-91		$	-27		$	-60		$	-95		$	95
	State			-37			11			-37			-10			-13			-2			7		State			35			-25			2			-6			―			11			27		State			21			30			29			21			5			1			42
	Foreign			151			―			―			―			―			―			―		Foreign			133			―			―			―			―			―			―		Foreign			164			―			―			―			―			―			―
	Total current income taxes			-9			60			-258			-80			-156			-23			-81		Total current income taxes			122			-26			-86			-54			6			37			―		Total current income taxes			148			-92			-62			-6			-55			-94			137
	Deferred income taxes																							Deferred income taxes																							Deferred income taxes
	Federal			1,129			464			555			316			326			93			276		Federal			513			408			226			162			121			72			-47		Federal			526			531			365			262			214			194			-38
	State			142			75			84			59			44			5			29		State			64			77			40			9			21			-9			-25		State			56			40			27			6			22			-2			-23
	Foreign			14			―			―			―			―			―			―		Foreign			20			―			―			―			―			―			―		Foreign			32			―			―			―			―			―			―
	Total deferred income taxes^(a)			1,285			539			639			375			370			98			305		Total deferred income taxes^(a)			597			485			266			171			142			63			-72		Total deferred income taxes^(a)			614			571			392			268			236			192			-61
	Investment tax credit amortization			-15			-5			-8			-7			-1			―			-1		Investment tax credit amortization			-14			-6			-8			-7			-1			-2			-1		Investment tax credit amortization			-10			-7			-7			-6			-1			-2			-2
	Income tax expense from continuing operations			1,261			594			373			288			213			75			223		Income tax expense (benefit) from continuing operations			705			453			172			110			147			98			-73		Income tax expense from continuing operations			752			472			323			256			180			96			74
	Tax benefit from discontinued operations			-27			―			-26			―			―			―			―		Tax expense from discontinued operations			24			―			29			―			―			―			―		Tax benefit from discontinued operations			―			―			-3			―			―			―			―
	Total income tax expense included in Consolidated Statements of Operations		$	1,234		$	594		$	347		$	288		$	213		$	75		$	223		Total income tax expense (benefit) included in Consolidated Statements of Operations		$	729		$	453		$	201		$	110		$	147		$	98		$	-73		Total income tax expense included in Consolidated Statements of Operations		$	752		$	472		$	320		$	256		$	180		$	96		$	74

	(a)	Includes benefits of net operating loss (NOL) carryforwards of $837 million at Duke Energy, $458 million at Progress Energy, $64 million at Duke Energy Progress, $301 million at Duke Energy Florida, $29 million at Duke Energy Ohio and $179 million at Duke Energy Indiana.																						(a)	Includes benefits of NOL carryforwards of $1,127 million at Duke Energy, $245 million at Duke Energy Carolinas, $357 million at Progress Energy, $257 million at Duke Energy Progress, $25 million at Duke Energy Florida, $99 million at Duke Energy Ohio and $205 million at Duke Energy Indiana.																						(a)	Includes benefits of NOL carryforwards of $274 million at Duke Energy, $79 million at Duke Energy Carolinas, $213 million at Progress Energy, $54 million at Duke Energy Progress, $41 million at Duke Energy Florida and $47 million at Duke Energy Ohio.

Schedule of Income before Income Tax, Domestic and Foreign	'																							'																							'
	Duke Energy Income from Continuing Operations before Income Taxes

			Years Ended December 31,
	(in millions)		2013			2012			2011
	Domestic			$	3,320		$	1,827		$	1,780
	Foreign				600			624			685
	Income from continuing operations before income taxes			$	3,920		$	2,451		$	2,465

Summary of Effective Tax Rates	'																							'																							'
	Statutory Rate Reconciliation
																										Year Ended December 31, 2012																							Year Ended December 31, 2011
	The following tables present a reconciliation of income tax expense at the U.S. federal statutory tax rate to the actual tax expense from continuing operations.																							(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
																								Income tax expense, computed at the statutory rate of 35 percent		$	858		$	461		$	185		$	134		$	145		$	96		$	-43		Income tax expense, computed at the statutory rate of 35 percent		$	863		$	457		$	319		$	270		$	173		$	102		$	85
			Year Ended December 31, 2013																					State income tax, net of federal income tax effect			64			34			33			1			14			1			1		State income tax, net of federal income tax effect			50			46			39			18			17			-1			13
	(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Tax differential on foreign earnings			-66			―			―			―			―			―			―		Tax differential on foreign earnings			-44			―			―			―			―			―			―
	Income tax expense, computed at the statutory rate of 35 percent		$	1,372		$	549		$	361		$	276		$	188		$	62		$	203		AFUDC equity income			-101			-54			-37			-24			-13			-2			-26		AFUDC equity income			-91			-59			-36			-25			-11			-2			-31
	State income tax, net of federal income tax effect			67			56			31			31			20			2			23		Renewable energy production tax credits			-25			―			―			―			―			―			―		Renewable energy production tax credits			-21			―			―			―			―			―			―
	Tax differential on foreign earnings			-45			―			―			―			―			―			―		Other items, net			-25			12			-9			-1			1			3			-5		Other items, net			-5			28			1			-7			1			-3			7
	AFUDC equity income			-55			-32			-18			-15			-3			―			-5		Income tax expense (benefit) from continuing operations		$	705		$	453		$	172		$	110		$	147		$	98		$	-73		Income tax expense from continuing operations		$	752		$	472		$	323		$	256		$	180		$	96		$	74
	Renewable energy production tax credits			-59			―			―			―			―			―			―		Effective tax rate			28.8	%		34.3	%		32.7	%		28.7	%		35.7	%		36	%		59.5	%	Effective tax rate			30.5	%		36.1	%		35.6	%		33.2	%		36.3	%		33.1	%		30.6	%
	Other items, net			-19			21			-1			-4			8			11			2
	Income tax expense from continuing operations		$	1,261		$	594		$	373		$	288		$	213		$	75		$	223
	Effective tax rate			32.2	%		37.8	%		36.2	%		36.5	%		39.6	%		42.2	%		38.4	%

Schedule of Deferred Tax Assets and Liabilities	'																							'																							'
	DEFERRED TAXES
																										31-Dec-12
	Net Deferred Income Tax Liability Components																							(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
																								Deferred credits and other liabilities		$	256		$	64		$	110		$	24		$	76		$	-10		$	22
			31-Dec-13																					Capital lease obligations			60			13			―			―			―			―			-1
	(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Pension, postretirement and other employee benefits			1,320			117			712			318			257			62			94
	Deferred credits and other liabilities		$	245		$	56		$	136		$	9		$	96		$	-13		$	9		Progress Energy merger purchase accounting adjustments^(a)			1,312			―			―			―			―			―			―
	Capital lease obligations			59			11			―			―			―			―			-2		Tax credits and NOL carryforwards			3,311			447			1,536			309			91			152			340
	Pension, postretirement and other employee benefits			649			18			341			119			145			23			54		Other			408			22			230			82			126			10			27
	Progress Energy merger purchase accounting adjustments^(a)			1,184			―			―			―			―			―			―		Valuation allowance			-226			―			-77			―			―			-1			―
	Tax credits and NOL carryforwards			4,307			488			1,965			396			365			165			521		Total deferred income tax assets			6,441			663			2,511			733			550			213			482
	Other			265			15			116			39			43			20			14		Investments and other assets			-1,093			-838			-112			-108			-6			-25			-18
	Valuation allowance			-192			―			-40			-1			―			―			―		Accelerated depreciation rates			-11,208			-4,289			-2,803			-2,178			-592			-1,823			-1,131
	Total deferred income tax assets			6,517			588			2,518			562			649			195			596		Regulatory assets and deferred debits			-3,819			-627			-1,775			-465			-1,318			-197			-185
	Investments and other assets			-1,396			-999			-209			-160			-49			-17			-7		Total deferred income tax liabilities			-16,120			-5,754			-4,690			-2,751			-1,916			-2,045			-1,334
	Accelerated depreciation rates			-12,615			-4,400			-3,663			-2,528			-1,160			-1,937			-1,591		Net deferred income tax liabilities		$	-9,679		$	-5,091		$	-2,179		$	-2,018		$	-1,366		$	-1,832		$	-852
	Regulatory assets and deferred debits			-3,185			-609			-1,389			-202			-1,159			-168			-117
	Total deferred income tax liabilities			-17,196			-6,008			-5,261			-2,890			-2,368			-2,122			-1,715		(a)	Primarily related to capital lease obligations and debt fair value adjustments.
	Net deferred income tax liabilities		$	-10,679		$	-5,420		$	-2,743		$	-2,328		$	-1,719		$	-1,927		$	-1,119

	(a)	Primarily related to capital lease obligations and debt fair value adjustments.

Summary of Tax Credit Carryforwards	'																							'																							'
	The following table presents the expiration of tax credits and NOL carryforwards.

			31-Dec-13
	(in millions)		Amount			Expiration Year
	Investment Tax Credits		$	498		2029	-	2033
	Alternative Minimum Tax Credits			1,028		Indefinite
	Federal NOL carryforwards			2,471		2030	-	2033
	State NOL carryforwards and credits^(a)			189		2014	-	2033
	Foreign NOL carryforwards^(b)			121		2015	-	2033
	Total tax credits and NOL carryforwards		$	4,307

	(a)	A valuation allowance of $83 million has been recorded on the state NOL carryforwards, state tax credits and state capital loss carryforwards, as presented in the Net Deferred Income Tax Liability Components table.
	(b)	A valuation allowance of $109 million has been recorded on the foreign NOL carryforwards, as presented in the Net Deferred Income Tax Liability Components table. Certain foreign NOL carryforwards have an indefinite expiration period.

Schedule of Balance Sheet Classification of Deferred Tax Assets and Liabilities	'																							'																							'
	Classification of Deferred Tax Assets (Liabilities) in the Consolidated Balance Sheets
																										31-Dec-12
			31-Dec-13																					(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				Current Assets: Other		$	732		$	90		$	359		$	144		$	152		$	21		$	1
	Current Assets: Other		$	1,373		$	286		$	540		$	229		$	110		$	85		$	52		Investments and Other Assets: Other			85			―			20			―			―			―			―
	Investments and Other Assets: Other			45			―			―			―			―			―			―		Current Liabilities: Other			-6			―			―			―			―			―			―
	Deferred Credits and Other Liabilities: Other			-12,097			-5,706			-3,283			-2,557			-1,829			-2,012			-1,171		Deferred Credits and Other Liabilities: Other			-10,490			-5,181			-2,558			-2,162			-1,518			-1,853			-853
	Net deferred income tax liabilities		$	-10,679		$	-5,420		$	-2,743		$	-2,328		$	-1,719		$	-1,927		$	-1,119		Net deferred income tax liabilities		$	-9,679		$	-5,091		$	-2,179		$	-2,018		$	-1,366		$	-1,832		$	-852

Schedule of Unrecognized Tax Benefits Roll Forward	'																							'																							'
	UNRECOGNIZED TAX BENEFITS
																										Year Ended December 31, 2012																							Year Ended December 31, 2011
	The following tables present changes to unrecognized tax benefits.																							(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
																								Unrecognized tax benefits — January 1		$	385		$	260		$	173		$	73		$	80		$	32		$	24		Unrecognized tax benefits — January 1		$	342		$	217		$	176		$	74		$	99		$	29		$	21
			Year Ended December 31, 2013																					Acquisitions			128			―			―			―			―			―			―		Unrecognized tax benefits increases (decreases)
	(in millions)		Duke Energy		Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana				Unrecognized tax benefits increases (decreases)																							Gross increases — tax positions in prior periods			49			42			88			19			66			4			3
	Unrecognized tax benefits — January 1		$	540		$	271		$	131		$	67		$	44		$	36		$	32		Gross increases — tax positions in prior periods			29			12			23			10			12			2			6		Gross decreases — tax positions in prior periods			-18			-8			-24			-14			-21			-5			-3
	Unrecognized tax benefits increases (decreases)																							Gross decreases — tax positions in prior periods			-4			―			-72			-19			-52			―			―		Gross increases — current period tax positions			16			9			9			8			1			4			3
	Gross decreases — tax positions in prior periods			-231			-100			-86			-45			-37			-36			-31		Gross increases — current period tax positions			28			15			8			4			4			4			4		Gross decreases — current period tax positions			―			―			-8			-4			-4			―			―
	Decreases due to settlements			-66			―			―			―			―			―			―		Gross decreases — current period tax positions			-9			-5			-1			-1			―			-2			-2		Decreases due to settlements			-4			―			-68			-10			-61			―			―
	Reduction due to lapse of statute of limitations			-13			―			-13			―			1			―			―		Decreases due to settlements			-13			-11			―			―			―			―			―		Total changes			43			43			-3			-1			-19			3			3
	Total changes			-310			-100			-99			-45			-36			-36			-31		Reduction due to lapse of statute of limitations			-4			―			―			―			―			―			―		Unrecognized tax benefits — December 31		$	385		$	260		$	173		$	73		$	80		$	32		$	24
	Unrecognized tax benefits — December 31		$	230		$	171		$	32		$	22		$	8		$	―		$	1		Total changes			155			11			-42			-6			-36			4			8
																								Unrecognized tax benefits — December 31		$	540		$	271		$	131		$	67		$	44		$	36		$	32

Schedule of Unrecognized Tax Benefits	'																							'																							'

	The following table includes additional information regarding the Duke Energy Registrants' unrecognized tax benefits. It is reasonably possible that Duke Energy and Duke Energy Carolinas will reflect an approximate $4 million reduction in unrecognized tax benefits within the next 12 months due to expected settlements. All other Duke Energy Registrants do not anticipate a material increase or decrease in unrecognized tax benefits within the next 12 months.

			31-Dec-13
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Indiana
	Amount that if recognized, would affect the effective tax rate or regulatory liability^(a)			$	128		$	116		$	2		$	1		$	1		$	1
	Amount that if recognized, would be recorded as a component of discontinued operations				8			―			―			―			―			―

	(a)	Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana are unable to estimate the specific amounts that would affect the effective tax rate versus the regulatory liability.

Summary of Income Tax Contingencies	'																							'																							'
	OTHER TAX MATTERS
																										Year Ended December 31, 2012																							Year Ended December 31, 2011
	The following tables include interest recognized in the Consolidated Statements of Operations and the Consolidated Balance Sheets.																							(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
																								Net interest income recognized related to income taxes		$	10		$	9		$	―		$	―		$	―		$	―		$	2		Net interest income recognized related to income taxes		$	12		$	5		$	24		$	6		$	22		$	―		$	―
			Year Ended December 31, 2013																					Net interest expense recognized related to income taxes			―			―			2			―			2			―			―		Net interest expense recognized related to income taxes			―			―			―			―			―			1			1
	(in millions)		Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana			Interest receivable related to income taxes			―			7			―			―			―			―			―		Interest receivable related to income taxes			8			5			―			―			―			―			―
	Net interest income recognized related to income taxes		$	2		$	2		$	6		$	7		$	―		$	4		$	1		Interest payable related to income taxes			7			―			17			8			9			3			1		Interest payable related to income taxes			―			―			21			8			7			3			3
	Interest payable related to income taxes			27			8			10			2			7			―			―

Other_Income_Expenses_Net_Tabl

Other Income & Expenses, Net (Tables)	12 Months Ended
Other Income & Expenses, Net (Tables)	Dec. 31, 2013															Dec. 31, 2012															Dec. 31, 2011
Component Of Other Income Expense Nonoperating [Line Items]	'															'															'
Schedule of Other Income and Expenses, Net	'															'															'
																	Year Ended December 31, 2012															Year Ended December 31, 2011
		Year Ended December 31, 2013														(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		Interest income	$	50	$	11	$	2	$	1	$	1	$	10	$	7	Interest income	$	53	$	10	$	2	$	1	$	1	$	14	$	14
	Interest income	$	26	$	1	$	7	$	1	$	3	$	6	$	6	Foreign exchange losses		-5		―		―		―		―		―		―	Foreign exchange gains		2		―		―		―		―		―		―
	Foreign exchange losses		-18		―		―		―		―		―		―	AFUDC equity		300		154		106		69		37		6		84	AFUDC equity		260		168		103		71		32		5		88
	AFUDC equity		157		91		50		42		8		1		15	Deferred returns		24		24		―		―		―		―		―	Contingent value obligations mark-to-market loss		―		―		-59		―		―		―		―
	Deferred returns		39		32		7		7		―		―		―	Other income (expense)		28		-4		22		9		1		-3		-1	Deferred returns		10		10		―		―		―		―		―
	Other income (expense)		58		-4		30		7		19		-3		-3	Other income and expense, net	$	397	$	185	$	130	$	79	$	39	$	13	$	90	Other income (expense)		51		-2		6		8		-3		―		-5
	Other income and expense, net	$	262	$	120	$	94	$	57	$	30	$	4	$	18																Other income and expense, net	$	376	$	186	$	52	$	80	$	30	$	19	$	97

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
Quarterly Financial Data (Tables)	Dec. 31, 2013												Dec. 31, 2012
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
													2012
	(in millions, except per share data)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating revenues		$	3,630	$	3,577	$	6,722	$	5,695	$	19,624
	2013												Operating income			495		786		1,078		767		3,126
	Operating revenues		$	5,898	$	5,879	$	6,709	$	6,112	$	24,598	Income from continuing operations			297		449		594		406		1,746
	Operating income			1,215		821		1,743		1,203		4,982	Net income			299		448		598		437		1,782
	Income from continuing operations			634		345		994		686		2,659	Net income attributable to Duke Energy Corporation			295		444		594		435		1,768
	Net income			634		342		1,008		692		2,676	Earnings per share:
	Net income attributable to Duke Energy Corporation			634		339		1,004		688		2,665	Income from continuing operations attributable to Duke Energy Corporation common shareholders
	Earnings per share:													Basic	$	0.66	$	0.99	$	0.84	$	0.57	$	3.01
	Income from continuing operations attributable to Duke Energy Corporation common shareholders													Diluted	$	0.66	$	0.99	$	0.84	$	0.57	$	3.01
		Basic	$	0.89	$	0.48	$	1.4	$	0.96	$	3.74	Net income attributable to Duke Energy Corporation common shareholders
		Diluted	$	0.89	$	0.48	$	1.4	$	0.96	$	3.74		Basic	$	0.66	$	0.99	$	0.85	$	0.62	$	3.07
	Net income attributable to Duke Energy Corporation common shareholders													Diluted	$	0.66	$	0.99	$	0.85	$	0.62	$	3.07
		Basic	$	0.89	$	0.48	$	1.42	$	0.97	$	3.77
		Diluted	$	0.89	$	0.48	$	1.42	$	0.97	$	3.76

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013^(a)												Costs to achieve Progress Energy merger (see Note 2)		$	-8	$	-7	$	-457	$	-164	$	-636
	Costs to achieve Progress Energy merger (see Note 2)		$	-55	$	-82	$	-88	$	-72	$	-297	Edwardsport IGCC charges (see Note 4)			-420		—		-180		-28		-628
	Crystal River Unit 3 charges (see Note 4)			—		-295		—		-57		-352	Voluntary Opportunity Plan deferral (see Note 19)			101		—		—		—		101
	Harris and Levy nuclear development charges (see Note 4)			—		-87		—		—		-87	Total		$	-327	$	-7	$	-637	$	-192	$	-1,163
	Gain on sale of DukeNet (see Note 12)			—		—		—		105		105
	Total		$	-55	$	-464	$	-88	$	-24	$	-631	(a)	Revised retail rates became effective in January for Duke Energy Florida, May for Duke Energy Ohio, June for Duke Energy Progress and September for Duke Energy Carolinas (see Note 4 for further information).

Duke Energy Carolinas [Member]	'												'
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
	DUKE ENERGY CAROLINAS												2012
													Operating revenues		$	1,501	$	1,616	$	1,939	$	1,609	$	6,665
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating income			475		386		440		216		1,517
	2013												Net income			266		211		258		130		865
	Operating revenues		$	1,729	$	1,591	$	1,919	$	1,715	$	6,954
	Operating income			434		351		604		420		1,809
	Net income			244		181		342		209		976

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013^(a)												Costs to achieve Progress Energy merger (see Note 2)		$	-4	$	-5	$	-184	$	-46	$	-239
	Costs to achieve Progress Energy merger (see Note 2)		$	-22	$	-35	$	-34	$	-29	$	-120	Voluntary Opportunity Plan deferral (see Note 19)			101		—		—		—		101
													Total		$	97	$	-5	$	-184	$	-46	$	-138

													(a)	Revised retail rates became effective in September in both North Carolina and South Carolina (see Note 4 for further information).

Progress Energy [Member]	'												'
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
													2012
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating revenues		$	2,102	$	2,288	$	2,788	$	2,227	$	9,405
	2013												Operating income			363		277		379		118		1,137
	Operating revenues		$	2,186	$	2,281	$	2,766	$	2,300	$	9,533	Income (loss) from continuing operations			141		68		154		-8		355
	Operating income			430		114		671		403		1,618	Net income			152		64		157		34		407
	Income (loss) from continuing operations			154		-13		328		190		659	Net income attributable to Parent			150		63		155		32		400
	Net income (loss)			154		-17		342		196		675
	Net income (loss) attributable to Parent			153		-17		341		195		672

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013^(a)												Costs to achieve the merger with Duke Energy (see Note 2)		$	-7	$	-20	$	-217	$	-82	$	-326
	Costs to achieve the merger with Duke Energy (see Note 2)		$	-19	$	-33	$	-42	$	-28	$	-122	Florida replacement power refund (see Note 4)			―		―		-100		―		-100
	Crystal River Unit 3 charges (see Note 4)			―		-295		―		-57		-352	Crystal River Unit 3 charges (see Note 4)			―		―		―		-192		-192
	Harris and Levy nuclear development charges (see Note 4)			―		-87		―		―		-87	Total		$	-7	$	-20	$	-317	$	-274	$	-618
	Total		$	-19	$	-415	$	-42	$	-85	$	-561

Duke Energy Progress [Member]	'												'
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
	DUKE ENERGY PROGRESS												2012
													Operating revenues		$	1,090	$	1,090	$	1,398	$	1,128	$	4,706
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating income			107		83		172		148		510
	2013												Net income			52		31		96		93		272
	Operating revenues		$	1,216	$	1,135	$	1,430	$	1,211	$	4,992
	Operating income			212		166		303		251		932
	Net income			110		77		175		138		500

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013^(a)												Costs to achieve the merger with Duke Energy (see Note 2)		$	-4	$	-12	$	-180	$	-36	$	-232
	Costs to achieve the merger with Duke Energy (see Note 2)		$	-11	$	-22	$	-32	$	-19	$	-84
	Harris nuclear development charges (see Note 4)			―		-22		―		―		-22
	Total		$	-11	$	-44	$	-32	$	-19	$	-106

Duke Energy Florida [Member]	'												'
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
	DUKE ENERGY FLORIDA												2012
													Operating revenues		$	1,010	$	1,196	$	1,388	$	1,095	$	4,689
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating income (loss)			255		196		207		-29		629
	2013												Net income (loss)			128		83		100		-45		266
	Operating revenues		$	968	$	1,142	$	1,332	$	1,085	$	4,527
	Operating income (loss)			221		-53		369		151		688
	Net income (loss)			110		-57		197		75		325

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013^(a)												Costs to achieve the merger with Duke Energy (see Note 2)		$	-3	$	-8	$	-37	$	-46	$	-94
	Costs to achieve the merger with Duke Energy (see Note 2)		$	-8	$	-11	$	-10	$	-9	$	-38	Replacement power refund (see Note 4)			―		―		-100		―		-100
	Crystal River Unit 3 charges (see Note 4)			―		-295		―		-57		-352	Crystal River Unit 3 charges (see Note 4)			―		―		―		-192		-192
	Levy nuclear development charges (see Note 4)			―		-65		―		―		-65	Total		$	-3	$	-8	$	-137	$	-238	$	-386
	Total		$	-8	$	-371	$	-10	$	-66	$	-455

Duke Energy Ohio [Member]	'												'
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
	DUKE ENERGY OHIO												2012
													Operating revenues		$	912	$	717	$	757	$	766	$	3,152
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating income			138		95		42		74		349
	2013												Net income			74		45		14		42		175
	Operating revenues		$	747	$	811	$	819	$	868	$	3,245
	Operating (loss) income			-17		108		116		44		251
	Net (loss) income			-21		58		59		6		102

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013^(a)												Costs to achieve Progress Energy merger (see Note 2)		$	-1	$	-1	$	-22	$	-12	$	-36
	Costs to achieve Progress Energy merger (see Note 2)		$	-4	$	-4	$	-4	$	-4	$	-16

Duke Energy Indiana [Member]	'												'
Quarterly Financial Information Disclosure [Line Items]	'												'
Schedule Of Quarterly Financial Information	'												'
	DUKE ENERGY INDIANA												2012
													Operating revenues		$	688	$	685	$	718	$	626	$	2,717
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		Operating (loss) income			-272		134		-30		93		-75
	2013												Net (loss) income			-167		77		-19		59		-50
	Operating revenues		$	724	$	700	$	755	$	747	$	2,926
	Operating income			181		168		203		181		733
	Net income			90		82		104		82		358

Schedule Of Unusual Or Infrequently Occurring Items	'												'
	(in millions)		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Total		2012
	2013												Costs to achieve Progress Energy merger (see Note 2)		$	-1	$	-1	$	-21	$	-11	$	-34
	Costs to achieve Progress Energy merger (see Note 2)		$	-4	$	-5	$	-5	$	-5	$	-19	Edwardsport IGCC charges (see Note 4)			-420		—		-180		-28		-628
													Total		$	-421	$	-1	$	-201	$	-39	$	-662

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Schedule of Unbilled Revenues with Restricted Receivables) (Details) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012		Dec. 31, 2011	Dec. 31, 2010
Stockholders' Equity Note [Abstract]	'	'		'	'
Stockholders' equity note, stock split, conversion ratio	'	0.3333		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Payments for the redemption of preferred stock	$96	'		'	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	1,501	1,424		2,110	1,670
Restricted Cash [Abstract]	'	'		'	'
Restricted cash	307	574		'	'
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	1,901	1,691		'	'
Coal held for electric generation	1,018	1,187		'	'
Oil, gas and other fuel held for electric generation	331	345		'	'
Inventory, Net, Total	3,250	3,223		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	2.80%	2.90%		3.20%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	937	920		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	30	34		35	'
Restricted receivables, allowance for doubtful accounts	43	44		40	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Collateral aready posted	135	163		'	'
Employee-related liabilities, current	621	725		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	602	466		293	'
Foreign Jurisdictions [Member]	'	'		'	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	1,086	'		'	'
Duke Energy Carolinas [Member]	'	'		'	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	23	19		289	153
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	654	535		'	'
Coal held for electric generation	374	488		'	'
Oil, gas and other fuel held for electric generation	37	39		'	'
Inventory, Net, Total	1,065	1,062		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	2.80%	2.80%		2.60%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	323	315		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	3	3		3	'
Restricted receivables, allowance for doubtful accounts	6	6		6	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Employee-related liabilities, current	198	203		'	'
Derivative, collateral, obligation to return cash	120	105		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	164	161		153	'
Duke Energy Carolinas [Member] \| State [Member] \| January 2014 [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Annual Reduction In Excise Taxes	160	'		'	'
Duke Energy Carolinas [Member] \| State [Member] \| Utility Franchise Tax Member [Member] \| Current [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	3.22%	'		'	'
Duke Energy Carolinas [Member] \| State [Member] \| Utility Franchise Tax Member [Member] \| January 2014 [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	0.00%	'		'	'
Duke Energy Carolinas [Member] \| State [Member] \| Electricity Sales Tax Member [Member] \| Current [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	3.00%	'		'	'
Duke Energy Carolinas [Member] \| State [Member] \| Electricity Sales Tax Member [Member] \| January 2014 [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	7.00%	'		'	'
Progress Energy [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Payments for the redemption of preferred stock	96	0		0	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	58	231		230	611
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	854	768		'	'
Coal held for electric generation	334	392		'	'
Oil, gas and other fuel held for electric generation	236	281		'	'
Inventory, Net, Total	1,424	1,441		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	2.50%	2.60%		2.30%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	189	187		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	14	16		27	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Collateral aready posted	10	59		'	'
Employee-related liabilities, current	214	304		'	'
Customer deposits, current	349	342		'	'
Derivative liabilities, current	0	221		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	304	317		315	'
Duke Energy Progress [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Payments for the redemption of preferred stock	62	0		0	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	21	18		20	230
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	567	499		'	'
Coal held for electric generation	187	232		'	'
Oil, gas and other fuel held for electric generation	99	97		'	'
Inventory, Net, Total	853	828		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	2.50%	2.70%		2.10%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	120	112		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	10	9		9	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Collateral aready posted	'	9		'	'
Employee-related liabilities, current	121	160		'	'
Customer deposits, current	129	120		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	115	113		110	'
Duke Energy Progress [Member] \| State [Member] \| January 2014 [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Annual Reduction In Excise Taxes	110	'		'	'
Duke Energy Progress [Member] \| State [Member] \| Utility Franchise Tax Member [Member] \| Current [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	3.22%	'		'	'
Duke Energy Progress [Member] \| State [Member] \| Utility Franchise Tax Member [Member] \| January 2014 [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	0.00%	'		'	'
Duke Energy Progress [Member] \| State [Member] \| Electricity Sales Tax Member [Member] \| Current [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	3.00%	'		'	'
Duke Energy Progress [Member] \| State [Member] \| Electricity Sales Tax Member [Member] \| January 2014 [Member]	'	'		'	'
Excise Taxes [Abstract]	'	'		'	'
Statutory Tax Rate	7.00%	'		'	'
Duke Energy Progress [Member] \| Minimum [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Redemption price	$101	'		'	'
Duke Energy Progress [Member] \| Maximum [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Redemption price	$110	'		'	'
Duke Energy Florida [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Payments for the redemption of preferred stock	34	0		0	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	16	131		16	249
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	287	269		'	'
Coal held for electric generation	147	160		'	'
Oil, gas and other fuel held for electric generation	137	184		'	'
Inventory, Net, Total	571	613		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	2.40%	2.50%		2.40%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	69	74		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	4	7		18	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Collateral aready posted	10	50		'	'
Employee-related liabilities, current	65	95		'	'
Customer deposits, current	220	222		'	'
Derivative liabilities, current	0	127		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	189	205		205	'
Duke Energy Florida [Member] \| Minimum [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Redemption price	$101	'		'	'
Duke Energy Florida [Member] \| Maximum [Member]	'	'		'	'
Preferred Stock Of Subsidiaries [Abstract]	'	'		'	'
Redemption price	$104.25	'		'	'
Duke Energy Ohio [Member]	'	'		'	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	36	31		99	228
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	117	135		'	'
Coal held for electric generation	65	82		'	'
Oil, gas and other fuel held for electric generation	47	10		'	'
Inventory, Net, Total	229	227		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	3.30%	3.20%		3.50%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	55	47		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	2	2		16	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Collateral aready posted	125	104		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	105	102		109	'
Duke Energy Ohio [Member] \| Current Collateral Assets [Member]	'	'		'	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Collateral aready posted	122	99		'	'
Duke Energy Ohio [Member] \| CRC [Member]	'	'		'	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	89	90		'	'
Duke Energy Indiana [Member]	'	'		'	'
Cash and Cash Equivalents [Abstract]	'	'		'	'
Cash and cash equivalents at end of period	15	36		16	54
Energy Related Inventory [Abstract]	'	'		'	'
Materials and supplies	193	161		'	'
Coal held for electric generation	238	216		'	'
Oil, gas and other fuel held for electric generation	3	3		'	'
Inventory, Net, Total	434	380		'	'
Depreciation Rate [Abstract]	'	'		'	'
Weighted-average depreciation rate	2.80%	3.30%		3.40%	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	5	3		'	'
Allowance For Doubtful Accounts [Abstract]	'	'		'	'
Receivables, allowance for doubtful accounts	1	1		1	'
Other Current Assets and Liabilities [Abstract]	'	'		'	'
Federal income taxes receivable	56	0		'	'
Employee-related liabilities, current	25	23	[1]	'	'
Derivative, collateral, obligation to return cash	40	37	[1]	'	'
Derivative liabilities, current	0	63		'	'
Excise Taxes [Abstract]	'	'		'	'
Excise Taxes Collected	29	33		31	'
Duke Energy Indiana [Member] \| CRC [Member]	'	'		'	'
Unbilled Receivables [Abstract]	'	'		'	'
Unbilled receivables, current	$144	$132		'	'

[1]	Does not exceed 5 percent of Total current liabilities on the Consolidated Balance Sheets at December 31, 2012.

Acquisitions_and_Sales_of_Othe

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

3 Months Ended

12 Months Ended

6 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Jun. 30, 2012

Dec. 31, 2012

Jul. 02, 2012

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jan. 12, 2012

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jan. 12, 2012

Commercial Power [Member]

Excluded From Pro Forma [Member]

D S Cornerstone [Member]

Progress Merger [Member]

Ibener [Member]

Midwest Generation Business [Member]

Minimum [Member]

Maximum [Member]

Duke Energy Carolinas [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Purchase Price Allocation Adjustments [Member]

Scenario Forecast [Member]

Midwest Generation Business [Member]

Duke Energy Vermillion [Member]

Scenario Forecast [Member]

Significant Acquisitions and Disposals [Line Items]

Costs to achieve the merger

$72,000,000

$88,000,000

$82,000,000

$55,000,000

$164,000,000

$457,000,000

$7,000,000

$8,000,000

$297,000,000

$636,000,000

$413,000,000

$85,000,000

$29,000,000

$34,000,000

$35,000,000

$22,000,000

$46,000,000

$184,000,000

$5,000,000

$4,000,000

$120,000,000

$239,000,000

$28,000,000

$42,000,000

$33,000,000

$19,000,000

$82,000,000

$217,000,000

$20,000,000

$7,000,000

$122,000,000

$326,000,000

$19,000,000

$32,000,000

$22,000,000

$11,000,000

$36,000,000

$180,000,000

$12,000,000

$4,000,000

$84,000,000

$232,000,000

$9,000,000

$10,000,000

$11,000,000

$8,000,000

$46,000,000

$37,000,000

$8,000,000

$3,000,000

$38,000,000

$94,000,000

$4,000,000

$12,000,000

$22,000,000

$1,000,000

$16,000,000

$36,000,000

$5,000,000

$4,000,000

$11,000,000

$21,000,000

$1,000,000

$19,000,000

$34,000,000

Proceeds

187,000,000

82,000,000

Transfer of Vermillion Generating Station

-28,000,000

26,000,000

Capital expenditures

5,526,000,000

5,501,000,000

4,363,000,000

1,695,000,000

1,908,000,000

2,272,000,000

2,490,000,000

2,366,000,000

2,256,000,000

1,567,000,000

1,525,000,000

1,426,000,000

915,000,000

809,000,000

813,000,000

434,000,000

514,000,000

499,000,000

545,000,000

718,000,000

1,066,000,000

68,000,000

Equity ownership interest

50.00%

62.50%

Construction and 12-year amortizing term loan facility

8,000,000

330,000,000

8,000,000

Proceeds from issuance of other long-term debt

319,000,000

Business combination, pro forma information, revenue of acquiree since acquisition date, actual

4,943,000,000

Business combination, pro forma information, earnings or loss of acquiree since acquisition date, actual

368,000,000

Cash paid

415,000,000

Property, plant and equipment

23,141,000,000

-138,000,000

383,000,000

Intangibles

30,000,000

Deferred tax

57,000,000

Working capital

3,204,000,000

8,000,000

Bridge loan

190,000,000

Goodwill

16,340,000,000

16,365,000,000

16,340,000,000

16,365,000,000

12,469,000,000

2,000,000

54,000,000

3,655,000,000

920,000,000

921,000,000

920,000,000

921,000,000

Revolving loan under credit agreement

200,000,000

Secured debt issuances

2,559,000,000

1,873,000,000

2,559,000,000

1,873,000,000

400,000,000

300,000,000

400,000,000

300,000,000

305,000,000

5,000,000

305,000,000

5,000,000

305,000,000

5,000,000

305,000,000

5,000,000

Other long-term assets, excluding goodwill

9,990,000,000

-4,000,000

Impairment charges

399,000,000

666,000,000

335,000,000

1,000,000,000

2,000,000,000

31,000,000

12,000,000

380,000,000

200,000,000

3,000,000

22,000,000

54,000,000

3,000,000

358,000,000

146,000,000

5,000,000

2,000,000

89,000,000

579,000,000

234,000,000

Assets held for sale

$3,500,000,000

Acquisitions_and_Sales_of_Othe1

Acquisitions and Sales of Other Assets (Accounting Charges) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	$34	[1]	$201	[1]	'
FERC mitigation	'		117		'
Community support and charitable contributions and other	34		92		'
Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		196		'
FERC mitigation	'		117		'
Community support and charitable contributions and other	'		169		'
Total charges related to the merger consummation	'		482		'
Duke Energy Carolinas [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	8		63		'
FERC mitigation	'		46		'
Community support and charitable contributions and other	14		56		'
Duke Energy Carolinas [Member] \| Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		63		'
FERC mitigation	'		46		'
Community support and charitable contributions and other	'		79		'
Total charges related to the merger consummation	'		188		'
Progress Energy [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	19		82		'
FERC mitigation	0		71		0
Community support and charitable contributions and other	20		36		0
Progress Energy [Member] \| Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		82		'
FERC mitigation	'		71		'
Community support and charitable contributions and other	'		74		'
Total charges related to the merger consummation	'		227		'
Duke Energy Progress [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	14		55		'
FERC mitigation	0		71		0
Community support and charitable contributions and other	20		36		0
Duke Energy Progress [Member] \| Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		55		'
FERC mitigation	'		71		'
Community support and charitable contributions and other	'		63		'
Total charges related to the merger consummation	'		189		'
Duke Energy Florida [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	5		27		'
Duke Energy Florida [Member] \| Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		27		'
Community support and charitable contributions and other	'		11		'
Total charges related to the merger consummation	'		38		'
Duke Energy Ohio [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	2		21		'
Duke Energy Ohio [Member] \| Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		21		'
Community support and charitable contributions and other	'		7		'
Total charges related to the merger consummation	'		28		'
Duke Energy Indiana [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	2		18		'
Duke Energy Indiana [Member] \| Progress Merger [Member]	'		'		'
Significant Acquisitions and Disposals [Line Items]	'		'		'
Severance charges	'		18		'
Community support and charitable contributions and other	'		6		'
Total charges related to the merger consummation	'		$24		'

[1]	Includes $5 million and $14 million of accelerated stock award expense and $2 million and $19 million of COBRA and healthcare reimbursement expenses for 2013 and 2012, respectively.

Acquisitions_and_Sales_of_Othe2

Acquisitions and Sales of Other Assets (Purchase Price Calculation) (Details) (USD $)	0 Months Ended
In Millions, except Share data, unless otherwise specified	Jul. 02, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'
Progress Energy common shares outstanding	'	706,000,000	704,000,000	445,000,000	443,000,000
Exchange ratio	87.08%	'	'	'	'
Duke Energy common shares issued for Progress Energy common shares outstanding	257,867,000	'	'	'	'
Closing price of Duke Energy common shares	$69.84	'	'	'	'
Purchase price for common shares	$18,009	'	'	'	'
Fair value of outstanding earned stock compensation awards	62	'	'	'	'
Total estimated purchase price	$18,071	'	'	'	'
Progress Energy [Member]	'	'	'	'	'
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'
Progress Energy common shares outstanding	296,116,000	100	100	'	'

Acquisitions_and_Sales_of_Othe3

Acquisitions and Sales of Other Assets (Purchase Price Allocation) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Jul. 02, 2012
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Jul. 02, 2012
Significant Acquisitions and Disposals [Line Items]	'	'	'
Goodwill	$16,340	$16,365	'
Total estimated purchase price	'	'	18,071
Progress Merger [Member]	'	'	'
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

Acquisitions_and_Sales_of_Othe4

Acquisitions and Sales of Other Assets (Pro Forma Financial Information) (Details) (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2012	Dec. 31, 2011
Significant Acquisitions and Disposals [Line Items]	'	'
Revenues	$23,976	$23,445
Net Income Attributable to Duke Energy Corporation	$2,417	$2,397
Basic Earnings Per Share	$3.43	$3.41
Diluted Earnings Per Share	$3.43	$3.41

Acquisitions_and_Sales_of_Othe5

Acquisitions and Sales of Other Assets (Narrative - Change in PPA) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Jul. 02, 2012	Dec. 31, 2013
In Millions, unless otherwise specified			Progress Merger [Member]	Purchase Price Allocation Adjustments [Member]
				Progress Merger [Member]
Significant Acquisitions and Disposals [Line Items]	'	'	'	'
Current assets	'	'	$3,204	'
Property, plant and equipment	'	'	23,141	-138
Goodwill	16,340	16,365	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)	12 Months Ended
Business Segments (Narrative) (Details)	Dec. 31, 2013
International Energy [Member] \| National Methanol Company [Member]	'
Segment Reporting Information [Line Items]	'
Equity ownership interest	25.00%
Duke Energy Progress [Member] \| North Carolina Electric Membership Corporation [Member]	'
Segment Reporting Information [Line Items]	'
Entity-wide revenue, major customer, percentage	10.00%

Business_Segments_Business_Seg

Business Segments (Business Segment Data) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

$6,112

$6,709

$5,879

$5,898

$5,695

$6,722

$3,577

$3,630

$24,598

$19,624

$14,529

Interest Expense

1,546

1,242

859

Depreciation and amortization

2,808

2,289

1,806

Equity in earnings (losses) of unconsolidated affiliates

122

148

160

Income Tax Expense or Benefit from Continuing Operations

1,261

705

752

Segment income

2,648

[1],[2],[3],[4],[5],[6],[7]

1,732

[4],[8]

1,705

[10],[9]

Add back Noncontrolling interest component

Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest

Net Income (Loss)

692

1,008

342

634

437

598

448

299

2,676

1,782

1,714

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

5,607

5,958

4,464

Segment assets

114,779

113,856

114,779

113,856

62,526

Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

24,598

[1],[2],[3]

19,624

14,529

Regulated Utilities [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

20,910

16,080

10,619

Interest Expense

986

806

568

Depreciation and amortization

2,323

1,827

1,383

Equity in earnings (losses) of unconsolidated affiliates

-1

-5

Income Tax Expense or Benefit from Continuing Operations

1,522

942

674

Segment income

2,504

[1],[2],[3],[4],[5],[6],[7]

1,744

[4],[8]

1,181

[10],[9]

Segments Notes To Tables [Abstract]

After-tax deferral of voluntary severance program expense

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

5,049

4,220

3,717

Segment assets

99,884

98,162

99,884

98,162

47,977

Regulated Utilities [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

20,871

[1],[2],[3]

16,042

10,586

Regulated Utilities [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Commercial Power [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

2,145

2,078

2,491

Interest Expense

Depreciation and amortization

250

228

230

Equity in earnings (losses) of unconsolidated affiliates

Income Tax Expense or Benefit from Continuing Operations

-104

-8

-2

Segment income

-3

[1],[2],[3],[4],[5],[6],[7]

[4],[8]

134

[10],[9]

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

268

1,038

492

Segment assets

6,955

6,992

6,955

6,992

6,939

Commercial Power [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

2,106

[1],[2],[3]

2,020

2,480

Commercial Power [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

International Energy [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,546

1,549

1,467

Interest Expense

Depreciation and amortization

100

Equity in earnings (losses) of unconsolidated affiliates

110

134

145

Income Tax Expense or Benefit from Continuing Operations

166

149

196

Segment income

408

[1],[2],[3],[4],[5],[6],[7]

439

[4],[8]

466

[10],[9]

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

551

114

Segment assets

4,998

5,406

4,998

5,406

4,539

International Energy [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,546

[1],[2],[3]

1,549

1,467

Total Reportable Segments [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

24,601

19,707

14,577

Interest Expense

1,136

946

702

Depreciation and amortization

2,673

2,154

1,703

Equity in earnings (losses) of unconsolidated affiliates

116

143

151

Income Tax Expense or Benefit from Continuing Operations

1,584

1,083

868

Segment income

2,909

[1],[2],[3],[4],[5],[6],[7]

2,270

[4],[8]

1,781

[10],[9]

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

5,384

5,809

4,323

Segment assets

111,837

110,560

111,837

110,560

59,455

Total Reportable Segments [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

24,523

[1],[2],[3]

19,611

14,533

Total Reportable Segments [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

163

Interest Expense

417

296

157

Depreciation and amortization

135

103

Equity in earnings (losses) of unconsolidated affiliates

Income Tax Expense or Benefit from Continuing Operations

-323

-378

-116

Segment income

-261

[1],[2],[3],[4],[5],[6],[7]

-538

[4],[8]

-76

[10],[9]

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

223

149

141

Segment assets

2,754

3,126

2,754

3,126

2,961

Other [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

[1],[2],[3]

-4

Other [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Intersegment Eliminations [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

-166

-143

-92

Interest Expense

-7

Segment Reporting Information Assets [Abstract]

Segment assets

188

170

188

170

110

Intersegment Eliminations [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

-166

-143

-92

Duke Energy Carolinas [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,715

1,919

1,591

1,729

1,609

1,939

1,616

1,501

6,954

6,665

6,493

Interest Expense

359

384

360

Depreciation and amortization

921

814

Income Tax Expense or Benefit from Continuing Operations

594

453

472

Net Income (Loss)

209

342

181

244

130

258

211

266

976

865

834

Segment Reporting Information Assets [Abstract]

Segment assets

31,273

30,642

31,273

30,642

Duke Energy Carolinas [Member] | Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment income

-97

-169

-46

Progress Energy [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

2,300

2,766

2,281

2,186

2,227

2,788

2,288

2,102

9,533

9,405

8,948

Interest Expense

680

740

725

Depreciation and amortization

883

747

701

Income Tax Expense or Benefit from Continuing Operations

373

172

323

Add back Noncontrolling interest component

Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest

-5

Net Income (Loss)

196

342

-17

154

157

152

675

407

582

Segment Reporting Information Assets [Abstract]

Segment assets

37,969

37,405

37,969

37,405

Progress Energy [Member] | Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Interest Expense

300

304

324

Segment income

-241

-379

-273

Duke Energy Progress [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,211

1,430

1,135

1,216

1,128

1,398

1,090

4,992

4,706

4,547

Interest Expense

201

207

184

Depreciation and amortization

534

535

514

Income Tax Expense or Benefit from Continuing Operations

288

110

256

Net Income (Loss)

138

175

110

500

272

516

Segment Reporting Information Assets [Abstract]

Segment assets

18,909

18,068

18,909

18,068

Duke Energy Progress [Member] | Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment income

-46

-139

-18

Duke Energy Florida [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,085

1,332

1,142

968

1,095

1,388

1,196

1,010

4,527

4,689

4,392

Interest Expense

180

255

239

Depreciation and amortization

330

192

169

Income Tax Expense or Benefit from Continuing Operations

213

147

180

Net Income (Loss)

197

-57

110

-45

100

128

325

266

314

Segment Reporting Information Assets [Abstract]

Segment assets

14,757

15,180

14,757

15,180

Duke Energy Florida [Member] | Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment income

-24

-58

-16

Duke Energy Ohio [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

868

819

811

747

766

757

717

912

3,245

3,152

3,181

Interest Expense

104

Depreciation and amortization

354

338

335

Income Tax Expense or Benefit from Continuing Operations

Segment income

102

175

194

[11]

Net Income (Loss)

-21

102

175

194

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

433

514

499

Segment assets

10,763

10,560

10,763

10,560

10,939

Duke Energy Ohio [Member] | PJM Interconnection, LLC

Segment Reporting Information Assets [Abstract]

Entity-wide revenue, major customer, percentage

37.00%

36.00%

24.00%

Duke Energy Ohio [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

3,245

[12]

3,152

[13]

3,181

[14]

Duke Energy Ohio [Member] | Regulated Utilities [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,765

1,746

1,474

Interest Expense

Depreciation and amortization

200

179

168

Income Tax Expense or Benefit from Continuing Operations

Segment income

151

159

133

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

375

427

375

Segment assets

6,649

6,434

6,649

6,434

6,293

Duke Energy Ohio [Member] | Regulated Utilities [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,765

1,745

1,474

Duke Energy Ohio [Member] | Regulated Utilities [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Duke Energy Ohio [Member] | Commercial Power [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,512

1,458

1,711

Interest Expense

Depreciation and amortization

154

159

167

Income Tax Expense or Benefit from Continuing Operations

-14

Segment income

-20

[11]

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

124

Segment assets

4,170

4,175

4,170

4,175

4,740

Duke Energy Ohio [Member] | Commercial Power [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

1,480

[12]

1,407

[13]

1,707

[14]

Duke Energy Ohio [Member] | Commercial Power [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Duke Energy Ohio [Member] | Total Reportable Segments [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

3,277

3,204

3,185

Interest Expense

104

Depreciation and amortization

354

338

335

Income Tax Expense or Benefit from Continuing Operations

116

104

Segment income

131

209

211

[11]

Segment Reporting Information Assets [Abstract]

Capital investments, expenditures and acquisitions

433

514

499

Segment assets

10,819

10,609

10,819

10,609

11,033

Duke Energy Ohio [Member] | Total Reportable Segments [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

3,245

[12]

3,152

[13]

3,181

[14]

Duke Energy Ohio [Member] | Total Reportable Segments [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Duke Energy Ohio [Member] | Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Income Tax Expense or Benefit from Continuing Operations

-2

-18

-8

Segment income

-29

-34

-17

Segment Reporting Information Assets [Abstract]

Segment assets

117

259

Duke Energy Ohio [Member] | Intersegment Eliminations [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

-32

-52

-4

Segment Reporting Information Assets [Abstract]

Segment assets

-155

-166

-155

-166

-353

Duke Energy Ohio [Member] | Intersegment Eliminations [Member] | Unaffiliated [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

Duke Energy Ohio [Member] | Intersegment Eliminations [Member] | Intersegment [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

-32

-52

-4

Duke Energy Indiana [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Operating revenues

747

755

700

724

626

718

685

688

2,926

2,717

2,622

Interest Expense

170

138

137

Depreciation and amortization

342

389

391

Income Tax Expense or Benefit from Continuing Operations

223

-73

Net Income (Loss)

104

-19

-167

358

-50

168

Segment Reporting Information Assets [Abstract]

Segment assets

10,548

10,008

10,548

10,008

Duke Energy Indiana [Member] | Other [Member]

Segment Reporting Information, Profit (Loss) [Abstract]

Segment income

($16)

($27)

($12)

[1]

In May 2013, Duke Energy Ohio implemented revised customer rates approved by the PUCO. This increase impacts Regulated Utilities. 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 Regulated Utilities. See Note 4 for additional information about the revised customer rates.

[3]

In September 2013, Duke Energy Carolinas implemented revised rates approved by the NCUC and the PSCSC. This increase impacts Regulated Utilities. See Note 4 for additional information about the revised customer rates.

[4]

Other includes after-tax costs to achieve the merger with Progress Energy. See Notes 2 and 25 for additional information about the merger and related costs.

[5]

Regulated Utilities recorded charges related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information about the Crystal River Unit 3 charges.

[6]

Regulated Utilities recorded an impairment charge related to Duke Energy Progress' Shearon Harris Nuclear Station (Harris) site. Regulated Utilities also recorded an impairment charge related to Duke Energy Florida's proposed nuclear plant in Levy County, Florida (Levy) site. See Note 4 for additional information about the Harris site and Levy site impairments.

[7]

Other includes gain from the sale of Duke Energy's ownership interest in DukeNet. See Note 12 for additional information on the sale of DukeNet.

[8]

Regulated Utilities recorded charges related to Duke Energy Indiana's IGCC project. See Note 4 for additional information about these charges. Regulated Utilities 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 19 for additional information about these expenses.

[9]

Regulated Utilities recorded charges related to Duke Energy Indiana's IGCC project. See Note 4 for additional information about these charges.

[10]

Commercial Power recorded charges to write-down the carrying value of certain emission allowances. See Note 11 for additional information about these charges.

[11]

Commercial Power recorded charges during the year ended December 31, 2011, to write-down the carrying value of certain emission allowances. See Note 11 for additional information.

[12]

Duke Energy Ohio earned approximately 37 percent of its consolidated operating revenues from PJM Interconnection, LLC (PJM) in 2013, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.

[13]

Duke Energy Ohio earned approximately 36 percent of its consolidated operating revenues from PJM in 2012, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.

[14]

Duke Energy Ohio earned approximately 24 percent of its consolidated operating revenues from PJM in 2011, all of which is included in the Commercial Power segment. These revenues relate to the sale of capacity and electricity from Commercial Power's nonregulated generation assets.

Business_Segments_Schedule_of_

Business Segments (Schedule of Revenue and Long-Lived Assets, By Geographical Area) (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Revenues from External Customers and Long-Lived Assets [Line Items]

Consolidated long-lived assets

$81,362

$81,611

$81,362

$81,611

$48,532

Consolidated revenue

6,112

6,709

5,879

5,898

5,695

6,722

3,577

3,630

24,598

19,624

14,529

U.S. [Member]

Revenues from External Customers and Long-Lived Assets [Line Items]

Consolidated long-lived assets

78,581

79,144

78,581

79,144

45,920

Consolidated revenue

23,053

18,078

13,062

Latin America [Member]

Revenues from External Customers and Long-Lived Assets [Line Items]

Consolidated long-lived assets

2,781

[1]

2,467

[1]

2,781

[1]

2,467

[1]

2,612

[1]

Consolidated revenue

$1,545

[1]

$1,546

[1]

$1,467

[1]

Change in amounts of long-lived assets in Latin America includes foreign currency translation adjustments on property, plant and equipment and other long-lived asset balances.

Regulatory_Matters_Narrative_D

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

12 Months Ended

24 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Duke Energy Carolinas [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Rate Case [Member]

Rate Case Step One [Member]

Rate Case Step Two [Member]

William State Lee III Nuclear Station [Member]

Rate Case [Member]

Rate Case Step One [Member]

Rate Case Step Two [Member]

Shearon Harris Nuclear Station [Member]

Removal Costs [Member]

2012 FPSC Settlement Agreement [Member]

2013 FPSC Settlement Agreement [Member]

Crystal River Unit 3 [Member]

Levy Nuclear Station [Member]

Electric Rate Case [Member]

Natural Gas Rate Case [Member]

MGP Remidiation [Member]

Capacity Rider Filing [Member]

RTO Realignment [Member]

Edwardsport IGCC Plant [Member]

NCUC [Member]

PSCSC [Member]

NCUC [Member]

PSCSC [Member]

NCUC [Member]

PSCSC [Member]

NCUC [Member]

New Generation Needs [Member]

Minimum [Member]

Maximum [Member]

Retail Portion [Member]

Minimum [Member]

Maximum [Member]

2013 FPSC Settlement Agreement [Member]

NEIL Settlement [Member]

2013 FPSC Settlement Agreement [Member]

PUCO [Member]

Edwardsport Event October 30, 2012 [Member]

Edwardsport Event November 20, 2007 [Member]

Edwardsport Event December 27, 2012 [Member]

Removal Costs Reduction Year One [Member]

Removal Costs Reduction Year Two [Member]

Removal Costs Reduction [Member]

Amount Subject To Cost Cap [Member]

Uprate And Dry Cask Storage Projects [Member]

Public Utilities, General Disclosures [Line Items]

Combined cycle capacity, MW

1,150

Additional generation capacity, MW

1,800

Estimated capital cost of new utility plant excluding AFUDC.

$3,150,000,000

Estimated capital cost of new utility plant, including AFUDC

1,985,000,000

2,595,000,000

Net property, plant and equipment

69,490,000,000

68,558,000,000

22,826,000,000

23,012,000,000

382,000,000

13,650,000,000

13,062,000,000

9,611,000,000

9,360,000,000

117,000,000

8,235,000,000

8,126,000,000

8,320,000,000

8,576,000,000

Approved rate increase amount by state commission

204,000,000

80,000,000

30,000,000

38,000,000

147,000,000

31,000,000

150,000,000

49,000,000

56,000,000

Requested rate increase amount to state commission

729,000,000

Rate increase begin date

'9/25/2013

'9/18/2013

'6/1/2013

'5/1/2013

Approved percentage rate increase 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%

10.50%

9.50%

11.50%

7.35%

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

399,000,000

666,000,000

335,000,000

31,000,000

12,000,000

22,000,000

54,000,000

3,000,000

22,000,000

358,000,000

146,000,000

295,000,000

65,000,000

5,000,000

2,000,000

89,000,000

579,000,000

234,000,000

631,000,000

897,000,000

Cost Cap for customers

1,466,000,000

MISO estimate of Duke Energy Ohio's MVP obligation

2,700,000,000

Recovery costs not sought

121,000,000

Repair costs, range of possible costs

900,000,000

1,300,000,000

Joint owner settlement amount

57,000,000

45,000,000

Net unrecovered investment

264,000,000

Amount of reduction to carrying amount of regulatory liabilities

114,000,000

178,000,000

250,000,000

Independent review repair costs

1,490,000,000

3,430,000,000

Decommissioning cost study estimate

1,180,000,000

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

130,000,000

Regulatory assets, current

895,000,000

737,000,000

221,000,000

295,000,000

127,000,000

77,000,000

221,000,000

179,000,000

97,000,000

57,000,000

46,000,000

126,000,000

118,000,000

Regulatory assets, noncurrent

9,191,000,000

11,004,000,000

1,727,000,000

1,527,000,000

1,384,000,000

1,845,000,000

47,000,000

2,729,000,000

3,321,000,000

134,000,000

1,310,000,000,000

323,000,000

50,000,000

471,000,000

579,000,000

74,000,000

810,000,000

717,000,000

Regulatory liability, noncurrent

$5,949,000,000

$5,584,000,000

$2,102,000,000

$2,576,000,000

$30,000,000

$45,000,000

$1,673,000,000

$1,538,000,000

$20,000,000

$618,000,000

$787,000,000

$490,000,000

$262,000,000

$254,000,000

$741,000,000

$782,000,000

Regulatory_Matters_Schedule_of

Regulatory Matters (Schedule of Regulatory Assets and Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	$895	$737
Regulatory assets, noncurrent	9,191	11,004
Regulatory assets	10,086	11,741
Regulatory liabilities - current	316	156
Regulatory liabilities - noncurrent	5,949	5,584
Regulatory liabilities	6,265	5,740
Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	5,308	4,827
Amounts To Be Refunded to Customers [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	151	290
Storm Reserve [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	145	125
Accrued Pension And Other Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	138	103
Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	177	55
Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	346	340
Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,723	3,306
Retired Generation Facilities [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,748	1,781
Debt Fair Value Adjustment [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,338	1,472
Asset Retirement Obligations Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,608	1,461
Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,115	1,373
Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	450	710
Demand Side Management And Energy Efficiency [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	371	322
Vacation Accrual [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	210	245
Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	94	162
Nuclear Deferral [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	262	142
Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	459	122
Gasification Services Agreement Buyout Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	75	95
Transmission Expansion Obligation [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	70	72
Manufactured Gas Plant Environmental Reserve [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	90	77
Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	473	401
Duke Energy Carolinas [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	295	221
Regulatory assets, noncurrent	1,527	1,727
Regulatory assets	1,822	1,948
Regulatory liabilities - current	65	78
Regulatory liabilities - noncurrent	2,576	2,102
Regulatory liabilities	2,641	2,180
Duke Energy Carolinas [Member] \| Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	2,423	1,928
Duke Energy Carolinas [Member] \| Storm Reserve [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	20	'
Duke Energy Carolinas [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	45	45
Duke Energy Carolinas [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	153	207
Duke Energy Carolinas [Member] \| Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	347	602
Duke Energy Carolinas [Member] \| Retired Generation Facilities [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	68	'
Duke Energy Carolinas [Member] \| Asset Retirement Obligations Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	123	48
Duke Energy Carolinas [Member] \| Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	555	731
Duke Energy Carolinas [Member] \| Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	98	88
Duke Energy Carolinas [Member] \| Demand Side Management And Energy Efficiency [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	140	107
Duke Energy Carolinas [Member] \| Vacation Accrual [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	82	85
Duke Energy Carolinas [Member] \| Nuclear Deferral [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	40	'
Duke Energy Carolinas [Member] \| Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	150	27
Duke Energy Carolinas [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	219	260
Progress Energy [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	353	256
Regulatory assets, noncurrent	4,155	5,292
Regulatory assets	4,508	5,548
Regulatory liabilities - current	207	28
Regulatory liabilities - noncurrent	2,292	2,469
Regulatory liabilities	2,499	2,497
Progress Energy [Member] \| Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	2,008	2,048
Progress Energy [Member] \| Amounts To Be Refunded to Customers [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	120	259
Progress Energy [Member] \| Storm Reserve [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	125	125
Progress Energy [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	132	10
Progress Energy [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	114	55
Progress Energy [Member] \| Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	750	1,650
Progress Energy [Member] \| Retired Generation Facilities [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,619	1,720
Progress Energy [Member] \| Asset Retirement Obligations Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	786	713
Progress Energy [Member] \| Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	331	401
Progress Energy [Member] \| Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	318	550
Progress Energy [Member] \| Demand Side Management And Energy Efficiency [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	152	121
Progress Energy [Member] \| Vacation Accrual [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	55	65
Progress Energy [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	37	109
Progress Energy [Member] \| Nuclear Deferral [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	222	142
Progress Energy [Member] \| Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	137	'
Progress Energy [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	101	77
Duke Energy Progress [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	127	77
Regulatory assets, noncurrent	1,384	1,845
Regulatory assets	1,511	1,922
Regulatory liabilities - current	63	10
Regulatory liabilities - noncurrent	1,673	1,538
Regulatory liabilities	1,736	1,548
Duke Energy Progress [Member] \| Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	1,637	1,503
Duke Energy Progress [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	'	10
Duke Energy Progress [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	99	35
Duke Energy Progress [Member] \| Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	269	769
Duke Energy Progress [Member] \| Retired Generation Facilities [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	241	128
Duke Energy Progress [Member] \| Asset Retirement Obligations Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	389	372
Duke Energy Progress [Member] \| Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	113	175
Duke Energy Progress [Member] \| Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	165	240
Duke Energy Progress [Member] \| Demand Side Management And Energy Efficiency [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	140	121
Duke Energy Progress [Member] \| Vacation Accrual [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	50	65
Duke Energy Progress [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	6	'
Duke Energy Progress [Member] \| Nuclear Deferral [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	77	'
Duke Energy Progress [Member] \| Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	19	'
Duke Energy Progress [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	42	52
Duke Energy Florida [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	221	179
Regulatory assets, noncurrent	2,729	3,321
Regulatory assets	2,950	3,500
Regulatory liabilities - current	144	18
Regulatory liabilities - noncurrent	618	787
Regulatory liabilities	762	805
Duke Energy Florida [Member] \| Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	371	401
Duke Energy Florida [Member] \| Amounts To Be Refunded to Customers [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	120	259
Duke Energy Florida [Member] \| Storm Reserve [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	125	125
Duke Energy Florida [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	132	'
Duke Energy Florida [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	14	20
Duke Energy Florida [Member] \| Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	438	754
Duke Energy Florida [Member] \| Retired Generation Facilities [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	1,378	1,592
Duke Energy Florida [Member] \| Asset Retirement Obligations Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	397	341
Duke Energy Florida [Member] \| Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	218	226
Duke Energy Florida [Member] \| Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	153	310
Duke Energy Florida [Member] \| Demand Side Management And Energy Efficiency [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	12	'
Duke Energy Florida [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	31	109
Duke Energy Florida [Member] \| Nuclear Deferral [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	145	142
Duke Energy Florida [Member] \| Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	118	'
Duke Energy Florida [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	60	26
Duke Energy Ohio [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	57	46
Regulatory assets, noncurrent	471	579
Regulatory assets	528	625
Regulatory liabilities - current	27	39
Regulatory liabilities - noncurrent	262	254
Regulatory liabilities	289	293
Duke Energy Ohio [Member] \| Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	241	236
Duke Energy Ohio [Member] \| Accrued Pension And Other Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	21	18
Duke Energy Ohio [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	27	39
Duke Energy Ohio [Member] \| Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	120	225
Duke Energy Ohio [Member] \| Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	72	82
Duke Energy Ohio [Member] \| Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	5	9
Duke Energy Ohio [Member] \| Demand Side Management And Energy Efficiency [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	79	94
Duke Energy Ohio [Member] \| Vacation Accrual [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	7	7
Duke Energy Ohio [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	14	1
Duke Energy Ohio [Member] \| Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	21	19
Duke Energy Ohio [Member] \| Transmission Expansion Obligation [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	74	72
Duke Energy Ohio [Member] \| Manufactured Gas Plant Environmental Reserve [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	90	77
Duke Energy Ohio [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	46	39
Duke Energy Indiana [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets - current	118	126
Regulatory assets, noncurrent	717	810
Regulatory assets	835	936
Regulatory liabilities - current	16	11
Regulatory liabilities - noncurrent	782	741
Regulatory liabilities	798	752
Duke Energy Indiana [Member] \| Removal Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	645	624
Duke Energy Indiana [Member] \| Amounts To Be Refunded to Customers [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	31	31
Duke Energy Indiana [Member] \| Accrued Pension And Other Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	77	68
Duke Energy Indiana [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory liabilities	45	29
Duke Energy Indiana [Member] \| Accrued Pension And Post Retirement [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	219	325
Duke Energy Indiana [Member] \| Retired Generation Facilities [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	61	61
Duke Energy Indiana [Member] \| Net Regulatory Asset Related To Income Taxes [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	157	158
Duke Energy Indiana [Member] \| Hedge Cost and Other Deferrals [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	29	63
Duke Energy Indiana [Member] \| Vacation Accrual [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	13	13
Duke Energy Indiana [Member] \| Deferred Fuel [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	43	52
Duke Energy Indiana [Member] \| Post-In-Service Carrying Costs And Deferred Operating Expense [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	151	76
Duke Energy Indiana [Member] \| Gasification Services Agreement Buyout Costs [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	75	95
Duke Energy Indiana [Member] \| Other [Member]	'	'
Regulatory Assets Liabilities [Line Items]	'	'
Regulatory assets	$87	$93

Regulatory_Matters_Refunds_Det

Regulatory Matters (Refunds) (Details) (Duke Energy Florida [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Florida Public Service Commission Settlement Agreement 2012 [Member]	'
Regulatory Assets Liabilities [Line Items]	'
Customer refunds to date	$129
2014	139
2015	10
2016	10
Total Customer Refunds To Be Paid	288	[1]
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	326
2014	164
Total Customer Refunds To Be Paid	490
Total Customer Refunds [Member]	'
Regulatory Assets Liabilities [Line Items]	'
Customer refunds to date	455
2014	303
2015	50
2016	70
Total Customer Refunds To Be Paid	878
Accelerated Regulatory Asset Recovery [Member]	'
Regulatory Assets Liabilities [Line Items]	'
2014	-37
2015	-37
2016	-56
Total Customer Refunds To Be Paid	-130
Net Customer Refunds [Member]	'
Regulatory Assets Liabilities [Line Items]	'
Customer refunds to date	455
2014	266
2015	13
2016	14
Total Customer Refunds To Be Paid	$748

[1]	See discussion under Customer Rate Matters section below.

Regulatory_Matters_Schedule_of1

Regulatory Matters (Schedule of MISO Exit fees)(Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Restructuring Reserve [Roll Forward]	'		'
Balance, beginning of period	$135		'
Cash reductions	-123		'
Provision/adjustments	52		'
Balance, end of period	64		'
Total regulatory assets	10,086		11,741
Duke Energy Ohio [Member]	'		'
Restructuring Reserve [Roll Forward]	'		'
Total regulatory assets	528		625
Duke Energy Ohio [Member] \| RTO Realignment [Member]	'		'
Restructuring Reserve [Roll Forward]	'		'
Balance, beginning of period	97		'
Cash reductions	-4		'
Provision/adjustments	2		'
Balance, end of period	95	[1]	'
Total regulatory assets	$74		'

[1]	As of December 31, 2013, $74 million is recorded as a Regulatory asset on Duke Energy Ohio's Consolidated Balance Sheets.

Regulatory_Matters_Schedule_of2

Regulatory Matters (Schedule of Net Carrying Value Of Facilities As Well As the Remaining Non-current Regulatory Assets) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

In Millions, unless otherwise specified

Generation Facilities To Be Retired [Member]

Duke Energy Carolinas [Member]

Progress Energy [Member]

Duke Energy Progress [Member]

Duke Energy Florida [Member]

Duke Energy Ohio [Member]

Duke Energy Indiana [Member]

Generation Facilities To Be Retired [Member]

Public Utilities, General Disclosures [Line Items]

Megawatt of potential plants to be retired

2,447

200

[1]

873

[2]

873

[2]

706

[3]

668

[4]

Net property, plant and equipment

$69,490

$68,558

$260

[5]

$23,012

$22,826

$14

[1],[5]

$23,382

$22,697

$113

[2],[5]

$13,650

$13,062

$9,611

$9,360

$113

[2],[5]

$8,235

$8,126

$10

[3],[5]

$8,576

$8,320

$123

[4],[5]

[1]

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.

[2]

Includes Crystal River Units 1 and 2.

[3]

Includes Beckjord Units 4 through 6 and Miami Fort Unit 6. 150 MW Beckjord Station Unit 4 was retired on February 17, 2014. Beckjord units have no remaining book value.

[4]

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.

[5]

Included in Property, plant and equipment, net as of December 31, 2013, on the Consolidated Balance Sheets.

Commitments_and_Contingencies_1

Commitments and Contingencies (Narrative) (Details) (USD $)	12 Months Ended
Commitments and Contingencies (Narrative) (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2009	Dec. 31, 2012
Insurance [Abstract]	'		'	'
Insured public liability limit per nuclear incident	$13,600,000,000		'	'
Primary nuclear liability program coverage	375,000,000		'	'
Excess nuclear liability program coverage	13,200,000,000		'	'
Pro rata assessment for each reactor owned for each incident exceeding public liability insurance	127,000,000		'	'
Annual payment limit to pro rata assessments	19,000,000		'	'
Industry aggregate limit	3,200,000,000		'	'
Sublimit for non-nuclear terrorist events	1,830,000,000		'	'
Number of licensed nuclear reactors	104		'	'
Primary property insurance coverage per nuclear facility	500,000,000		'	'
Sublimit property damage losses	1,500,000,000		'	'
Percentage of insurance coverage during initial weeks of covered event	100.00%		'	'
Initial weeks of insurance coverage	52		'	'
Percentage of insurance coverage during additional weeks of covered event	80.00%		'	'
Additional weeks of insurance coverage	110		'	'
Sublimit accidental outage recovery	328,000,000		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Probable insurance recoveries	649,000,000	[1],[2],[3]	'	781,000,000	[1],[2],[3]
Minimum [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Estimated cost of complying with recently issued and proposed EPA regulations	4,500,000,000		'	'
Estimated amount of ash released, in tons	30,000		'	'
Estimated amount of ash basin water released, in gallons	24,000,000		'	'
Maximum [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Estimated cost of complying with recently issued and proposed EPA regulations	5,500,000,000		'	'
Estimated amount of ash released, in tons	39,000		'	'
Estimated amount of ash basin water released, in gallons	27,000,000		'	'
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 related to litigation settlement	22,000,000		'	'
Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	74,000,000		'	'
Duke Energy Carolinas [Member]	'		'	'
Insurance [Abstract]	'		'	'
Primary property insurance deductible per occurrence obligation	10,000,000		'	'
Maximum potentional retroactive premium assessments for primary property insurance	42,000,000		'	'
Maximum potentional retroactive premium assessments for excess property insurance	36,000,000		'	'
Maximum potentional retroactive premium assessments for accidental outage insurance	29,000,000		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Probable insurance recoveries	649,000,000	[1],[2],[3]	'	781,000,000	[1],[2],[3]
Duke Energy Carolinas [Member] \| McGuire Nuclear Station [Member]	'		'	'
Insurance [Abstract]	'		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	750,000,000		'	'
Excess property, decontamination and decommissioning liability insurance additional shared limits	1,000,000,000		'	'
Accidental outage insurance coverage per week	4,000,000		'	'
Accidental outage insurance coverage policy limit	490,000,000		'	'
Duke Energy Carolinas [Member] \| Oconee Nuclear Station [Member]	'		'	'
Insurance [Abstract]	'		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	750,000,000		'	'
Excess property, decontamination and decommissioning liability insurance additional shared limits	1,000,000,000		'	'
Accidental outage insurance coverage per week	3,000,000		'	'
Accidental outage insurance coverage policy limit	378,000,000		'	'
Duke Energy Carolinas [Member] \| Catawba Nuclear Station [Member]	'		'	'
Insurance [Abstract]	'		'	'
Primary property insurance deductible per occurrence obligation	3,000,000		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	2,250,000,000		'	'
Accidental outage insurance coverage per week	4,000,000		'	'
Accidental outage insurance coverage policy limit	490,000,000		'	'
Duke Energy Carolinas [Member] \| New Source Review Provisions Of Clean Air Act [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Maximum civil penalties per day for each violation	37,500		'	'
Duke Energy Carolinas [Member] \| Asbestos Issue [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Asbestos-related injuries and damages reserves	616,000,000		'	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	31		'	'
Asbestos-related injuries and damages reserves	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	96		'	'
Asbestos-related injuries and damages reserves	24,000,000		'	'
Duke Energy Carolinas [Member] \| Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	29,000,000		'	'
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
Progress Energy [Member] \| Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	5,000,000		'	'
Duke Energy Progress [Member]	'		'	'
Insurance [Abstract]	'		'	'
Primary property insurance deductible per occurrence obligation	10,000,000		'	'
Maximum potentional retroactive premium assessments for primary property insurance	33,000,000		'	'
Maximum potentional retroactive premium assessments for excess property insurance	32,000,000		'	'
Maximum potentional retroactive premium assessments for accidental outage insurance	14,000,000		'	'
Duke Energy Progress [Member] \| Robinson Nuclear Station [Member]	'		'	'
Insurance [Abstract]	'		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	750,000,000		'	'
Excess property, decontamination and decommissioning liability insurance additional shared limits	1,000,000,000		'	'
Accidental outage insurance coverage per week	2,000,000		'	'
Accidental outage insurance coverage policy limit	308,000,000		'	'
Duke Energy Progress [Member] \| Brunswick Nuclear Station [Member]	'		'	'
Insurance [Abstract]	'		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	750,000,000		'	'
Excess property, decontamination and decommissioning liability insurance additional shared limits	1,000,000,000		'	'
Accidental outage insurance coverage per week	3,000,000		'	'
Accidental outage insurance coverage policy limit	406,000,000		'	'
Duke Energy Progress [Member] \| Shearon Harris Nuclear Station [Member]	'		'	'
Insurance [Abstract]	'		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	750,000,000		'	'
Excess property, decontamination and decommissioning liability insurance additional shared limits	1,000,000,000		'	'
Accidental outage insurance coverage per week	3,000,000		'	'
Accidental outage insurance coverage policy limit	364,000,000		'	'
Duke Energy Progress [Member] \| Spent Nuclear Fuels [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Gain contingency, unrecorded amount	84,000,000		'	'
Duke Energy Progress [Member] \| Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	2,000,000		'	'
Duke Energy Florida [Member]	'		'	'
Insurance [Abstract]	'		'	'
Primary property insurance deductible per occurrence obligation	10,000,000		'	'
Maximum potentional retroactive premium assessments for primary property insurance	6,000,000		'	'
Maximum potentional retroactive premium assessments for excess property insurance	4,000,000		'	'
Duke Energy Florida [Member] \| Crystal River Unit 3 [Member]	'		'	'
Insurance [Abstract]	'		'	'
Excess property, decontamination and decommissioning liability insurance limits on each nuclear plant	560,000,000		'	'
Duke Energy Florida [Member] \| Spent Nuclear Fuels [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Gain contingency, unrecorded amount	21,000,000		'	'
Duke Energy Florida [Member] \| Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	3,000,000		'	'
Duke Energy Ohio [Member] \| Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	35,000,000		'	'
Duke Energy Indiana [Member] \| Edwardsport IGCC Plant [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Gain contingency, unrecorded amount	560,000,000		'	'
Duke Energy Indiana [Member] \| Environmental Reserves [Member]	'		'	'
Valuation and Qualifying Accounts [Abstract]	'		'	'
Loss contingency, range of possible loss, portion not acccrued	$5,000,000		'	'

[1]	Classified in the respective Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities.
[2]	Classified in the respective Consolidated Balance Sheets in Other within Investments and Other Assets and Receivables.
[3]	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 $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	$824	[1],[2]	$846	[1],[2]
Probable insurance recoveries	649	[1],[3],[4]	781	[1],[3],[4]
Duke Energy Carolinas [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	616	[1],[2]	751	[1],[2]
Probable insurance recoveries	649	[1],[3],[4]	781	[1],[3],[4]
Progress Energy [Member]	'		'
Loss Contingencies [Line Items]	'		'
Reserves for legal matters	78	[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]	Classified in the respective 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]	Classified in the respective 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 $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	$75	$61	$88
Provision/adjustments	26	39	6
Cash reductions	-22	-25	-33
Ending balance	79	75	61
Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	525	'	'
Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	625	'	'
Duke Energy Carolinas [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	12	12	13
Provision/adjustments	'	1	'
Cash reductions	-1	-1	-1
Ending balance	11	12	12
Duke Energy Carolinas [Member] \| Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	40	'	'
Duke Energy Carolinas [Member] \| Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	50	'	'
Duke Energy Ohio [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	15	28	50
Provision/adjustments	20	5	5
Cash reductions	-8	-18	-27
Ending balance	27	15	28
Duke Energy Ohio [Member] \| Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	35	'	'
Duke Energy Ohio [Member] \| Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	50	'	'
Duke Energy Indiana [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	8	9	11
Provision/adjustments	1	3	1
Cash reductions	-2	-4	-3
Ending balance	7	8	9
Duke Energy Indiana [Member] \| Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	425	'	'
Duke Energy Indiana [Member] \| Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	485	'	'
Progress Energy [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	33	23	35
Provision/adjustments	4	19	10
Cash reductions	-10	-9	-22
Ending balance	27	33	23
Progress Energy [Member] \| Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	25	'	'
Progress Energy [Member] \| Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	40	'	'
Duke Energy Progress [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	14	11	12
Provision/adjustments	-1	5	1
Cash reductions	-5	-2	-2
Ending balance	8	14	11
Duke Energy Progress [Member] \| Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	10	'	'
Duke Energy Progress [Member] \| Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	15	'	'
Duke Energy Florida [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Beginning balance	19	12	23
Provision/adjustments	5	14	9
Cash reductions	-5	-7	-20
Ending balance	19	19	12
Duke Energy Florida [Member] \| Minimum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	15	'	'
Duke Energy Florida [Member] \| Maximum [Member]	'	'	'
Accrual for Environmental Loss Contingencies [Roll Forward]	'	'	'
Estimated cost of complying with EPA Mercury and Air Toxics Standards	$25	'	'

Commitments_and_Contingencies_3

Commitments and Contingencies (PurchPower)(Details) (Public Utilities Purchased Power [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Duke Energy Progress [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, share of plant output being purchased	100.00%
2014	$36	[1]
2015	36	[1]
2016	36	[1]
2017	37	[1]
2018	37	[1]
Thereafter	69	[1]
Total	251	[1]
Duke Energy Progress [Member] \| Maximum [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, date of contract expiration	'2022
Duke Energy Progress [Member] \| Minimum [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, date of contract expiration	'2019
Duke Energy Florida [Member]	'
Unconditional Purchase Obligations [Abstract]	'
2014	288	[2]
2015	295	[2]
2016	295	[2]
2017	288	[2]
2018	303	[2]
Thereafter	2,139	[2]
Total	3,608	[2]
Duke Energy Florida [Member] \| Maximum [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, date of contract expiration	'2025
Long-term contract for purchase of electric power, share of plant output being purchased	100.00%
Duke Energy Florida [Member] \| Minimum [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, date of contract expiration	'2014
Long-term contract for purchase of electric power, share of plant output being purchased	2.00%
Duke Energy Ohio [Member]	'
Unconditional Purchase Obligations [Abstract]	'
2014	250	[3]
2015	97	[3]
Total	$347	[3]
Duke Energy Ohio [Member] \| Maximum [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, date of contract expiration	'2015
Long-term contract for purchase of electric power, share of plant output being purchased	24.00%
Duke Energy Ohio [Member] \| Minimum [Member]	'
Unconditional Purchase Obligations [Abstract]	'
Long-term contract for purchase of electric power, date of contract expiration	'2014
Long-term contract for purchase of electric power, share of plant output being purchased	1.00%

[1]	Contracts represent 100 percent of net plant output.
[2]	Contracts represent between 2 percent and 100 percent of net plant output.
[3]	Contracts represent between 1 percent and 24 percent of net plant output.

Commitments_and_Contingencies_4

Commitments and Contingencies (Future Minimum Payments for Operating and Capital Leases) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leased Assets	'	'	'
Rental expense on operating leases	$321	$232	$104
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	175	'	'
2015	159	'	'
2016	147	'	'
2017	137	'	'
2018	117	'	'
Thereafter	1,034	'	'
Total future minimum lease payments	1,769	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	171	'	'
2015	167	'	'
2016	169	'	'
2017	166	'	'
2018	176	'	'
Thereafter	1,453	'	'
Minimum annual payments	2,302	'	'
Less amount representing interest	-786	'	'
Total	1,516	'	'
Duke Energy Carolinas [Member]	'	'	'
Operating Leased Assets	'	'	'
Rental expense on operating leases	39	38	43
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	34	'	'
2015	29	'	'
2016	24	'	'
2017	20	'	'
2018	15	'	'
Thereafter	67	'	'
Total future minimum lease payments	189	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	6	'	'
2015	6	'	'
2016	6	'	'
2017	6	'	'
2018	6	'	'
Thereafter	25	'	'
Minimum annual payments	55	'	'
Less amount representing interest	-27	'	'
Total	28	'	'
Progress Energy [Member]	'	'	'
Operating Leased Assets	'	'	'
Rental expense on operating leases	225	232	104
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	93	'	'
2015	89	'	'
2016	90	'	'
2017	89	'	'
2018	78	'	'
Thereafter	773	'	'
Total future minimum lease payments	1,212	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	47	'	'
2015	47	'	'
2016	47	'	'
2017	46	'	'
2018	45	'	'
Thereafter	475	'	'
Minimum annual payments	707	'	'
Less amount representing interest	-454	'	'
Total	253	'	'
Duke Energy Progress [Member]	'	'	'
Operating Leased Assets	'	'	'
Rental expense on operating leases	153	164	88
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	55	'	'
2015	51	'	'
2016	51	'	'
2017	50	'	'
2018	40	'	'
Thereafter	459	'	'
Total future minimum lease payments	706	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	20	'	'
2015	20	'	'
2016	21	'	'
2017	21	'	'
2018	21	'	'
Thereafter	261	'	'
Minimum annual payments	364	'	'
Less amount representing interest	-275	'	'
Total	89	'	'
Duke Energy Florida [Member]	'	'	'
Operating Leased Assets	'	'	'
Rental expense on operating leases	72	68	15
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	39	'	'
2015	39	'	'
2016	39	'	'
2017	39	'	'
2018	38	'	'
Thereafter	314	'	'
Total future minimum lease payments	508	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	26	'	'
2015	27	'	'
2016	26	'	'
2017	26	'	'
2018	25	'	'
Thereafter	213	'	'
Minimum annual payments	343	'	'
Less amount representing interest	-179	'	'
Total	164	'	'
Duke Energy Ohio [Member]	'	'	'
Operating Leased Assets	'	'	'
Rental expense on operating leases	14	14	19
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	12	'	'
2015	11	'	'
2016	8	'	'
2017	7	'	'
2018	5	'	'
Thereafter	18	'	'
Total future minimum lease payments	61	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	9	'	'
2015	7	'	'
2016	6	'	'
2017	3	'	'
2018	3	'	'
Thereafter	2	'	'
Minimum annual payments	30	'	'
Less amount representing interest	-3	'	'
Total	27	'	'
Duke Energy Indiana [Member]	'	'	'
Operating Leased Assets	'	'	'
Rental expense on operating leases	22	20	24
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	18	'	'
2015	15	'	'
2016	12	'	'
2017	9	'	'
2018	7	'	'
Thereafter	8	'	'
Total future minimum lease payments	69	'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'	'	'
2014	5	'	'
2015	4	'	'
2016	4	'	'
2017	2	'	'
2018	2	'	'
Thereafter	28	'	'
Minimum annual payments	45	'	'
Less amount representing interest	-30	'	'
Total	$15	'	'

Debt_and_Credit_Facilities_Nar

Debt and Credit Facilities (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Other Debt Matters [Abstract]	'	'
Subsidiary debt guaranteed by parent	$811,000,000	$734,000,000
Demand notes, maximum amount available for sale	3,000,000,000	'
Demand notes, maximum amount outstanding	1,500,000,000	'
Principal amount of demand notes	836,000,000	395,000,000
Other Loans [Abstract]	'	'
Other loans outstanding against cash surrender value of life insurance policies	571,000,000	496,000,000
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'
Duke Energy Carolinas [Member]	'	'
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'
Progress Energy [Member]	'	'
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'
Duke Energy Progress [Member]	'	'
Other Loans [Abstract]	'	'
Other loans outstanding against cash surrender value of life insurance policies	$48,000,000	'
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'
Duke Energy Florida [Member]	'	'
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'
Duke Energy Ohio [Member]	'	'
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'
Duke Energy Indiana [Member]	'	'
Restrictive Debt Covenants [Abstract]	'	'
Debt to total capitalization percentage, for each borrower	0.65	'

Debt_and_Credit_Facilities_Sum

Debt and Credit Facilities (Summary of Debt and Related Terms) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Debt Instrument [Line Items]	'		'
Unsecured Debt	13,550		12,722
Secured Debt	2,559		1,873
First mortgage bonds	17,831	[1]	17,856	[1]
Capital leases	1,516		1,689
Junior subordinated debt	'		309
Other debt	8		8
Tax exempt bonds	2,356	[2]	2,357	[2]
Notes Payable And Commercial Paper	1,289	[3]	1,507	[4]
Fair value hedge carrying value adjustment	9		12
Unamortized debt discount and premium, net	1,977	[5]	2,185	[6]
Total debt	41,095		40,518
Short-term notes payable and commercial paper	-839		-1,057
Current maturities of long-term debt	-2,104		-3,110
Total long-term debt	38,152	[7]	36,351	[8]
Derf [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	'		300	[9]
Unsecured Debt [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	5.18%		5.44%
Debt maturity date, start	31-Dec-14		31-Dec-13
Debt maturity date, end	31-Dec-73		31-Dec-39
Secured Debt [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	2.69%		3.08%
Debt maturity date, start	31-Dec-14		31-Dec-13
Debt maturity date, end	31-Dec-37		31-Dec-37
First Mortgage Bonds [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	4.90%		5.00%
Debt maturity date, start	31-Dec-15		31-Dec-13
Debt maturity date, end	31-Dec-43		31-Dec-42
Capital Lease Obligations [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	5.23%		5.19%
Debt maturity date, start	31-Dec-14		31-Dec-13
Debt maturity date, end	31-Dec-51		31-Dec-51
Junior Subordinated Debt [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	'		7.10%
Debt maturity date, end	'		31-Dec-39
Other Debt [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	4.77%		4.77%
Debt maturity date, end	31-Dec-27		31-Dec-27
Tax Exempt Bonds [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	1.28%		1.39%
Debt maturity date, start	31-Dec-14		31-Dec-14
Debt maturity date, end	31-Dec-41		31-Dec-41
Short term obligations classified as long-term debt	471		471
Non-Recourse Notes Payable Of VIEs [Member]	'		'
Debt Instrument [Line Items]	'		'
Total long-term debt	1,966		852
Notes Payable And Commercial Paper [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	1.02%		0.83%
Short term obligations classified as long-term debt	450		450
Revolving Loan [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	200	[10]	200	[10]
Purchase Accounting Adjustments [Member]	'		'
Debt Instrument [Line Items]	'		'
Unamortized debt discount and premium, net	2,067		2,311
Duke Energy Carolinas [Member]	'		'
Debt Instrument [Line Items]	'		'
Unsecured Debt	1,157		1,159
Secured Debt	400		300
First mortgage bonds	6,161	[1]	6,562	[1]
Capital leases	30		32
Tax exempt bonds	395	[2]	395	[2]
Money pool borrowings	300		300
Fair value hedge carrying value adjustment	9		10
Unamortized debt discount and premium, net	-16		-17
Total debt	8,436		8,741
Current maturities of long-term debt	-47		-406
Total long-term debt	8,389	[7]	8,335	[8]
Duke Energy Carolinas [Member] \| Derf [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	'		300	[9]
Duke Energy Carolinas [Member] \| Tax Exempt Bonds [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	75		75
Duke Energy Carolinas [Member] \| Non-Recourse Notes Payable Of VIEs [Member]	'		'
Debt Instrument [Line Items]	'		'
Total long-term debt	400		300
Duke Energy Carolinas [Member] \| Notes Payable And Commercial Paper [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	300		300
Progress Energy [Member]	'		'
Debt Instrument [Line Items]	'		'
Unsecured Debt	4,150		4,150
Secured Debt	305		5
First mortgage bonds	8,450	[1]	8,775	[1]
Capital leases	327		339
Junior subordinated debt	'		309
Tax exempt bonds	910	[2]	910	[2]
Money pool borrowings	1,213		455
Unamortized debt discount and premium, net	-27		-60
Total debt	15,328		14,883
Short-term money pool borrowings	-1,213		-455
Current maturities of long-term debt	-485		-843
Total long-term debt	13,630	[7]	13,585
Progress Energy [Member] \| Junior Subordinated Debt [Member]	'		'
Debt Instrument [Line Items]	'		'
Weighted-average rate	'		7.10%
Progress Energy [Member] \| Non-Recourse Notes Payable Of VIEs [Member]	'		'
Debt Instrument [Line Items]	'		'
Total long-term debt	300		'
Duke Energy Progress [Member]	'		'
Debt Instrument [Line Items]	'		'
Secured Debt	305		5
First mortgage bonds	4,125	[1]	4,025	[1]
Capital leases	148	[11]	150	[12]
Tax exempt bonds	669	[2]	669	[2]
Money pool borrowings	462		364
Unamortized debt discount and premium, net	-12		-9
Total debt	5,697		5,204
Short-term money pool borrowings	-462		-364
Current maturities of long-term debt	-174		-407
Total long-term debt	5,061	[7]	4,433
Duke Energy Progress [Member] \| Non-Recourse Notes Payable Of VIEs [Member]	'		'
Debt Instrument [Line Items]	'		'
Total long-term debt	300		'
Duke Energy Progress [Member] \| Purchase Accounting Adjustments [Member]	'		'
Debt Instrument [Line Items]	'		'
Capital leases	144		158
Duke Energy Florida [Member]	'		'
Debt Instrument [Line Items]	'		'
Unsecured Debt	150		150
First mortgage bonds	4,325	[1]	4,750	[1]
Capital leases	179	[11]	189	[12]
Tax exempt bonds	241	[2]	241	[2]
Money pool borrowings	181		'
Unamortized debt discount and premium, net	-9		-10
Total debt	5,067		5,320
Short-term money pool borrowings	-181		0
Current maturities of long-term debt	-11		-435
Total long-term debt	4,875		4,885
Duke Energy Florida [Member] \| Purchase Accounting Adjustments [Member]	'		'
Debt Instrument [Line Items]	'		'
Capital leases	838		907
Duke Energy Ohio [Member]	'		'
Debt Instrument [Line Items]	'		'
Unsecured Debt	805		805
First mortgage bonds	900	[1]	700	[1]
Capital leases	27		35
Other debt	8		8
Tax exempt bonds	479	[2]	479	[2]
Money pool borrowings	43		245
Fair value hedge carrying value adjustment	'		2
Unamortized debt discount and premium, net	-31		-32
Total debt	2,231		2,242
Short-term money pool borrowings	-43		-245
Current maturities of long-term debt	-47		-261
Total long-term debt	2,141		1,736
Duke Energy Ohio [Member] \| Tax Exempt Bonds [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	111		111
Duke Energy Indiana [Member]	'		'
Debt Instrument [Line Items]	'		'
Unsecured Debt	744		1,146
First mortgage bonds	2,319	[1]	1,819	[1]
Capital leases	20		23
Tax exempt bonds	573	[2]	573	[2]
Money pool borrowings	150		231
Unamortized debt discount and premium, net	-10		-9
Total debt	3,796		3,783
Short-term money pool borrowings	0		-81
Current maturities of long-term debt	-5		-405
Total long-term debt	3,791		3,297
Duke Energy Indiana [Member] \| Tax Exempt Bonds [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	285		285
Duke Energy Indiana [Member] \| Notes Payable And Commercial Paper [Member]	'		'
Debt Instrument [Line Items]	'		'
Short term obligations classified as long-term debt	150		150

[1]	Substantially all electric utility fixed assets are mortgaged under mortgage bond indentures.
[2]	Substantially all tax-exempt bonds are secured by first mortgage bonds or letters of credit.
[3]	Includes $450 million that was classified as Long-term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energybs ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 49 days.
[4]	Includes $450 million that was classified as Long-term Debt on the Consolidated Balance Sheets due to the existence of long-term credit facilities that back-stop these commercial paper balances, along with Duke Energybs ability and intent to refinance these balances on a long-term basis. The weighted-average days to maturity was 18 days.
[5]	Duke Energy includes $2,067 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.
[6]	Duke Energy includes $2,311 million in purchase accounting adjustments related to the merger with Progress Energy. See Note 2 for additional information.
[7]	Includes $1,966 million for Duke Energy, $400 million for Duke Energy Carolinas and $300 million for Progress Energy and Duke Energy Progress related to consolidated VIEs.
[8]	Includes $852 million for Duke Energy and $300 million for Duke Energy Carolinas related to consolidated VIEs.
[9]	Duke Energy Receivables Finance Company, LLC (DERF) is a wholly owned limited liability company of Duke Energy Carolinas. See Note 17 for further information.
[10]	Instrument has a term of less than one year with the right to extend the maturity date for additional one-year periods with a final maturity date no later than December 2026.
[11]	Duke Energy includes $144 million and $838 million of capital lease purchase accounting adjustments related to Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as leases in their financial statements because of grandfathering provisions in GAAP.
[12]	Duke Energy includes $158 million and $907 million of capital lease purchase accounting adjustments for Duke Energy Progress and Duke Energy Florida, respectively, related to power purchase agreements that are not accounted for as leases on their financial statements because of grandfathering provisions in GAAP.

Debt_and_Credit_Facilities_Sum1

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

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Millions, unless otherwise specified

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

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

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

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

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

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

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

December 2013 0.852% Secured ARS Maturing December 2016 [Member]

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

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

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

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

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

March 2012 3.15% Unsecured Maturing April 2022 [Member]

August 2012 1.63% Senior Notes Maturing August 2017 [Member]

August 2012 3.05% Senior Notes Maturing August 2022 [Member]

April 2012 2.64% Secured Maturing September 2024 [Member]

December 2012 2.77% Secured Maturing March 2013 [Member]

December 2012 4.74% Secured Maturing March 2013 [Member]

December 2012 1.01% Secured Maturing June 2013 [Member]

December 2012 1.56% Secured Maturing December 2025 [Member]

March 2012 4.20% First Mortgage Bonds Maturing March 2042 [Member]

May 2012 2.80% First Mortgage Bonds Maturing May 2022 [Member]

May 2012 4.10% First Mortgage Bonds Maturing May 2042 [Member]

September 2012 4.00% First Mortgage Bonds Maturing September 2042 [Member]

November 2012 0.65% First Mortgage Bonds Maturing November 2015 [Member]

November 2012 3.85%First Mortgage Bonds Maturing November 2042 [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]

Unsecured Debt [Member]

Secured Debt [Member]

Bridge Loan [Member]

Secured Debt [Member]

First Mortgage Bonds [Member]