UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)



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

For the quarterly period ended ~~June~~September 30, 2014



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

For the transition period from to

________________________



Commission file number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, and Telephone Number	IRS Employer Identification No.

1-32853	DUKE ENERGY CORPORATION (a Delaware corporation) 550 South Tryon Street Charlotte, North Carolina 28202-1803 704-382-3853	20-2777218



Commission file number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number and IRS Employer Identification Number	Commission file number	Registrant, State of Incorporation or Organization, Address of Principal Executive Offices, Telephone Number and IRS Employer Identification Number
1-4928	DUKE ENERGY CAROLINAS, LLC (a North Carolina limited liability company) 526 South Church Street Charlotte, North Carolina 28202-1803 704-382-3853 56-0205520	1-3274	DUKE ENERGY FLORIDA, INC. (a Florida corporation) 299 First Avenue North St. Petersburg, Florida 33701 704-382-3853 59-0247770
1-15929	PROGRESS ENERGY, INC. (a North Carolina corporation) 410 South Wilmington Street Raleigh, North Carolina 27601-1748 704-382-3853 56-2155481	1-1232	DUKE ENERGY OHIO, INC. (an Ohio corporation) 139 East Fourth Street Cincinnati, Ohio 45202 704-382-3853 31-0240030
1-3382	DUKE ENERGY PROGRESS, INC. (a North Carolina corporation) 410 South Wilmington Street Raleigh, North Carolina 27601-1748 704-382-3853 56-0165465	1-3543	DUKE ENERGY INDIANA, INC. (an Indiana corporation) 1000 East Main Street Plainfield, Indiana 46168 704-382-3853 35-0594457

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.



Duke Energy Corporation (Duke Energy)	Yes x	No ¨	Duke Energy Florida, Inc. (Duke Energy Florida)	Yes x	No ¨
Duke Energy Carolinas, LLC (Duke Energy Carolinas)	Yes x	No ¨	Duke Energy Ohio, Inc. (Duke Energy Ohio)	Yes x	No ¨
Progress Energy, Inc. (Progress Energy)	Yes x	No ¨	Duke Energy Indiana, Inc. (Duke Energy Indiana)	Yes x	No ¨
Duke Energy Progress, Inc. (Duke Energy Progress)	Yes x	No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).



Duke Energy	Yes x	No ¨	Duke Energy Florida	Yes x	No ¨
Duke Energy Carolinas	Yes x	No ¨	Duke Energy Ohio	Yes x	No ¨
Progress Energy	Yes x	No ¨	Duke Energy Indiana	Yes x	No ¨
Duke Energy Progress	Yes x	No ¨

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



Duke Energy	Large accelerated filer x	Accelerated filer ¨	Non-accelerated filer ¨	Smaller reporting company ¨
Duke Energy Carolinas	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	Smaller reporting company ¨
Progress Energy	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	Smaller reporting company ¨
Duke Energy Progress	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	Smaller reporting company ¨
Duke Energy Florida	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	Smaller reporting company ¨
Duke Energy Ohio	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	Smaller reporting company ¨
Duke Energy Indiana	Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x	Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).



Duke Energy	Yes ¨	No x	Duke Energy Florida	Yes ¨	No x
Duke Energy Carolinas	Yes ¨	No x	Duke Energy Ohio	Yes ¨	No x
Progress Energy	Yes ¨	No x	Duke Energy Indiana	Yes ¨	No x
Duke Energy Progress	Yes ¨	No x

Number of shares of Common Stock outstanding at ~~August~~November 4, 2014:



Registrant	Description	Shares
Duke Energy	Common Stock, $0.001 par value	~~707,271,675~~707,290,608
Duke Energy Carolinas	All of the registrant's limited liability company member interests are directly owned by Duke Energy.
Progress Energy	All of the registrant's common stock is directly owned by Duke Energy.
Duke Energy Progress	All of the registrant’s common stock is indirectly owned by Duke Energy.
Duke Energy Florida	All of the registrant’s common stock is indirectly owned by Duke Energy.
Duke Energy Ohio	All of the registrant’s common stock is indirectly owned by Duke Energy.
Duke Energy Indiana	All of the registrant’s common stock is indirectly owned by Duke Energy.

This combined Form 10-Q is filed separately by seven registrants: Duke Energy, Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana (collectively the Duke Energy Registrants). Information contained herein relating to any individual registrant is filed by such registrant solely on its own behalf. Each registrant makes no representation as to information relating exclusively to the other registrants.

Duke Energy Carolinas, Progress Energy, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio and Duke Energy Indiana meet the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and are therefore filing this form with the reduced disclosure format specified in General Instructions H(2) of Form 10-Q.

TABLE OF CONTENTS



	Cautionary Statement Regarding ~~Forward Looking~~Forward-Looking Information

PART I. FINANCIAL INFORMATION
Item 1.	Financial Statements

	Duke Energy Corporation Financial Statements	5

	Duke Energy Carolinas, LLC Financial Statements	10

	Progress Energy, Inc. Financial Statements	14

	Duke Energy Progress, Inc. Financial Statements	18

	Duke Energy Florida, Inc. Financial Statements	22

	Duke Energy Ohio, Inc. Financial Statements	26

	Duke Energy Indiana, Inc. Financial Statements	30

	Combined Notes to Condensed Consolidated Financial Statements
	Note 1 - Organization and Basis of Presentation	34
	Note 2 - Acquisitions and Dispositions	3637
	Note 3 - Business Segments	3739
	Note 4 - Regulatory Matters	4243
	Note 5 - Commitments and Contingencies	4748
	Note 6 - Debt and Credit Facilities	5355
	Note 7 - ~~Goodwill~~	54
	~~Note 8 - Related Party Transactions~~	55
	~~Note 9 - Derivatives and Hedging~~Asset Retirement Obligations	56
	Note 8 - Goodwill	57
	Note 9 - Related Party Transactions	58
	Note 10 - Derivatives and Hedging	59
	Note 11 - Investments in Debt and Equity Securities	67
	~~Note 11 - Fair Value Measurements~~	7370
	Note 12 - ~~Variable Interest Entities~~Fair Value Measurements	8376
	Note 13 - ~~Common Stock~~Variable Interest Entities	8886
	Note 14 - ~~Stock-Based Compensation~~Common Stock	8991
	Note 15 - ~~Employee Benefit Plans~~Stock-Based Compensation	8992
	Note 16 - ~~Income Taxes~~Employee Benefit Plans	9392
	Note 17 - Income Taxes	96
	Note 18 - Subsequent Events	9396

Item 2.	~~Management’s~~Management's Discussion and Analysis of Financial Condition and Results of Operations	9497

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	~~119~~124

Item 4.	Controls and Procedures	~~119~~124

PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	~~120~~125

Item 1A.	Risk Factors	~~120~~125

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	~~120~~125

Item 6.	Exhibits	~~121~~126

	Signatures	~~123~~128

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This document includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based on management’s beliefs and assumptions. These forward-looking statements are identified by terms and phrases such as “anticipate,” “believe,” “intend,” “estimate,” “expect,” “continue,” “should,” “could,” “may,” “plan,” “project,” “predict,” “will,” “potential,” “forecast,” “target,” “guidance,” “outlook,” and similar expressions. Forward-looking statements involve risks and uncertainties that may cause actual results to be materially different from the results predicted. Factors that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to:


◦	State, federal and foreign legislative and regulatory initiatives, including costs of compliance with existing and future environmental requirements or climate change, as well as rulings that affect cost and investment recovery or have an impact on rate structures or market prices;


◦	The extent and timing of the costs and liabilities relating to the Dan River ash basin release and compliance with current and any future regulatory changes related to the management of coal ash;


◦	The ability to recover eligible costs, including those associated with future significant weather events, and earn an adequate return on investment through the regulatory process;


◦	The costs of decommissioning Crystal River Unit 3 could prove to be more extensive than are currently identified and all costs may not be fully recoverable through the regulatory process;


◦	The risk that the credit ratings of the company or its subsidiaries may be different from what the companies expect;


◦	Costs and effects of legal and administrative proceedings, settlements, investigations and claims;


◦	Industrial, commercial and residential growth or decline in service territories or customer bases resulting from customer usage patterns, including energy efficiency efforts and use of alternative energy sources, including self-generation and distributed generation technologies;


◦	Additional competition in electric markets and continued industry consolidation;


◦	Political and regulatory uncertainty in other countries in which Duke Energy conducts business;


◦	The influence of weather and other natural phenomena on operations, including the economic, operational and other effects of severe storms, hurricanes, droughts and tornadoes;


◦	The ability to successfully operate electric generating facilities and deliver electricity to customers;


◦	The impact on facilities and business from a terrorist attack, cybersecurity threats, data security breaches, and other catastrophic events;


◦	The inherent risks associated with the operation and potential construction of nuclear facilities, including environmental, health, safety, regulatory and financial risks;


◦	The timing and extent of changes in commodity prices, interest rates and foreign currency exchange rates and the ability to recover such costs through the regulatory process, where appropriate, and their impact on liquidity positions and the value of underlying assets;


◦	The results of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general economic conditions;


◦	Declines in the market prices of equity and fixed income securities and resultant cash funding requirements for defined benefit pension plans, other post-retirement benefit plans, and nuclear decommissioning trust funds;


◦	Changes in rules for regional transmission organizations, including changes in rate designs and new and evolving capacity markets, and risks related to obligations created by the default of other participants;


◦	The ability to control operation and maintenance costs;


◦	The level of creditworthiness of counterparties to transactions;


◦	Employee workforce factors, including the potential inability to attract and retain key personnel;


◦	The ability of subsidiaries to pay dividends or distributions to Duke Energy Corporation holding company (the Parent);


◦	The performance of projects undertaken by our nonregulated businesses and the success of efforts to invest in and develop new opportunities;


◦	The effect of accounting pronouncements issued periodically by accounting standard-setting bodies;


◦	The impact of potential goodwill impairments;


◦	The ability to reinvest retained earnings of foreign subsidiaries or repatriate such earnings on a tax-free basis; and


◦	The ability to successfully complete future merger, acquisition or divestiture plans.

In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than described. Forward-looking statements speak only as of the date they are made; the Duke Energy Registrants undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise that occur after that date.

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Operations

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
(in millions, except per-share amounts)	2014			2013			2014			2013			2014			2013			2014			2013
Operating Revenues
Regulated electric	$	5,167		$	4,834		$	10,745		$	9,723		$	5,861		$	5,685		$	16,549		$	15,355
Nonregulated electric, natural gas and other	675			951			1,499			1,775			449			449			1,403			1,415
Regulated natural gas	107			94			329			279			85			83			414			362
Total operating revenues	5,949			5,879			12,573			11,777			6,395			6,217			18,366			17,132
Operating Expenses
Fuel used in electric generation and purchased power - regulated	1,808			1,678			3,808			3,381			2,132			2,013			5,940			5,394
Fuel used in electric generation and purchased power - nonregulated	436			447			845			901			148			130			410			435
Cost of natural gas and other	43			43			165			147			27			18			181			132
Operation, maintenance and other	1,467			1,504			2,973			2,925			1,409			1,402			4,254			4,211
Depreciation and amortization	761			678			1,551			1,338			788			672			2,305			1,940
Property and other taxes	318			323			676			666			275			319			936			972
Impairment charges	6			386			1,388			386			1			2			81			388
Total operating expenses	4,839			5,059			11,406			9,744			4,780			4,556			14,107			13,472
Gains on Sales of Other Assets and Other, net	6			1			7			3
Gains (Losses) on Sales of Other Assets and Other, net													4			(1		)	11			3
Operating Income	1,116			821			1,174			2,036			1,619			1,660			4,270			3,663
Other Income and Expenses
Equity in earnings of unconsolidated affiliates	33			22			69			58			28			32			97			91
Other income and expenses, net	89			48			184			128			109			55			293			182
Total other income and expenses	122			70			253			186			137			87			390			273
Interest Expense	413			381			819			748			405			378			1,212			1,125
Income From Continuing Operations Before Income Taxes	825			510			608			1,474			1,351			1,369			3,448			2,811
Income Tax Expense from Continuing Operations	209			165			82			495			460			423			1,081			909
Income From Continuing Operations	616			345			526			979			891			946			2,367			1,902
Loss From Discontinued Operations, net of tax	(3		)	(3		)	(6		)	(3		)
Income (Loss) From Discontinued Operations, net of tax													378			62			(578		)	82
Net Income	613			342			520			976			1,269			1,008			1,789			1,984
Less: Net Income Attributable to Noncontrolling Interests	4			3			8			3
Less: Net Income (Loss) Attributable to Noncontrolling Interests													(5		)	4			3			7
Net Income Attributable to Duke Energy Corporation	$	609		$	339		$	512		$	973		$	1,274		$	1,004		$	1,786		$	1,977

Earnings Per Share - Basic and Diluted
Income from continuing operations attributable to Duke Energy Corporation common shareholders
Basic	$	0.86		$	0.48		$	0.73		$	1.37		$	1.25		$	1.33		$	3.33		$	2.67
Diluted	$	0.86		$	0.48		$	0.73		$	1.37		$	1.25		$	1.33		$	3.33		$	2.67
Income from discontinued operations attributable to Duke Energy Corporation common shareholders
Income (Loss) from discontinued operations attributable to Duke Energy Corporation common shareholders
Basic	$	—		$	—		$	(0.01	)	$	—		$	0.55		$	0.09		$	(0.81	)	$	0.12
Diluted	$	—		$	—		$	(0.01	)	$	—		$	0.55		$	0.09		$	(0.81	)	$	0.12
Net Income attributable to Duke Energy Corporation common shareholders
Basic	$	0.86		$	0.48		$	0.72		$	1.37		$	1.80		$	1.42		$	2.52		$	2.79
Diluted	$	0.86		$	0.48		$	0.72		$	1.37		$	1.80		$	1.42		$	2.52		$	2.79
Weighted-average shares outstanding
Basic	707			706			707			705			707			706			707			706
Diluted	707			706			707			706			707			706			707			706

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Comprehensive Income

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
(in millions)	2014			2013			2014			2013			2014			2013			2014			2013
Net Income	$	613		$	342		$	520		$	976		$	1,269		$	1,008		$	1,789		$	1,984
Other Comprehensive Income (Loss), net of tax
Other Comprehensive Loss, net of tax
Foreign currency translation adjustments	28			(133		)	52			(129		)	(102		)	(8		)	(50		)	(137		)
Pension and OPEB adjustments	1			2			—			5			1			—			1			5
Net unrealized gain on cash flow hedges^(a)	—			44			—			54
Reclassification into earnings and other adjustments to cash flow hedges	(9		)	—			(9		)	—
Unrealized gain (loss) on investments in available-for-sale securities	2			(4		)	2			(4		)
Other Comprehensive Income (Loss), net of tax	22			(91		)	45			(74		)
Net unrealized gains (losses) on cash flow hedges^(a)													2			1			(10		)	55
Reclassification into earnings from cash flow hedges													2			1			5			1
Unrealized (losses) gains on investments in available-for-sale securities													—			(1		)	2			(5		)
Reclassification into earnings from available-for-sale-securities													—			3			—			3
Other Comprehensive Loss, net of tax													(97		)	(4		)	(52		)	(78		)
Comprehensive Income	635			251			565			902			1,172			1,004			1,737			1,906
Less: Comprehensive Income (Loss) Attributable to Noncontrolling Interests	4			(1		)	9			(1		)
Less: Comprehensive (Loss) Income Attributable to Noncontrolling Interests													(1		)	4			8			3
Comprehensive Income Attributable to Duke Energy Corporation	$	631		$	252		$	556		$	903		$	1,173		$	1,000		$	1,729		$	1,903


(a)	Net of ~~$14 million~~insignificant tax expense and ~~$18~~$5 million tax benefit for the three and nine months ended September 30, 2014 and $1 million tax benefit and $17 million tax expense for the three ~~months~~ and ~~six~~nine months ended ~~June~~September 30, 2013.

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	2,008		$	1,501		$	1,931		$	1,501
Short-term investments	—			44
Receivables (net of allowance for doubtful accounts of $18 at June 30, 2014 and $30 at December 31, 2013)	877			1,286
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $54 at June 30, 2014 and $43 at December 31, 2013)	2,118			1,719
Short-Term investments							—			44
Receivables (net of allowance for doubtful accounts of $16 at September 30, 2014 and $30 at December 31, 2013)							854			1,286
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $52 at September 30, 2014 and $43 at December 31, 2013)							2,069			1,719
Inventory	3,056			3,250			3,200			3,250
Assets held for sale	409			—			335			—
Regulatory assets	1,349			895			1,232			895
Other	1,698			1,821			1,954			1,821
Total current assets	11,515			10,516			11,575			10,516
Investments and Other Assets
Investments in equity method unconsolidated affiliates	381			390			350			390
Nuclear decommissioning trust funds	5,417			5,132			5,374			5,132
Goodwill	16,343			16,340			16,331			16,340
Assets held for sale	2,195			107			2,718			107
Other	3,227			3,432			3,287			3,432
Total investments and other assets	27,563			25,401			28,060			25,401
Property, Plant and Equipment
Cost	100,885			103,115			104,140			103,115
Accumulated depreciation and amortization	(33,977		)	(33,625		)	(34,545		)	(33,625		)
Net property, plant and equipment	66,908			69,490			69,595			69,490
Regulatory Assets and Deferred Debits
Regulatory assets	9,009			9,191			10,252			9,191
Other	178			181			174			181
Total regulatory assets and deferred debits	9,187			9,372			10,426			9,372
Total Assets	$	115,173		$	114,779		$	119,656		$	114,779
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	1,782		$	2,391		$	1,801		$	2,391
Notes payable and commercial paper	1,867			839			1,787			839
Taxes accrued	522			551			704			551
Interest accrued	453			440			476			440
Current maturities of long-term debt	1,887			2,104			1,156			2,104
Liabilities associated with assets held for sale	271			7			284			7
Regulatory liabilities	140			316			175			316
Other	1,786			1,996			1,868			1,996
Total current liabilities	8,708			8,644			8,251			8,644
Long-term Debt	38,706			38,152
Long-Term Debt							38,702			38,152
Deferred Credits and Other Liabilities
Deferred income taxes	12,014			12,097			12,989			12,097
Investment tax credits	435			442			431			442
Accrued pension and other post-retirement benefit costs	1,263			1,322			1,231			1,322
Liabilities associated with assets held for sale	75			66			57			66
Asset retirement obligations	5,030			4,950			8,499			4,950
Regulatory liabilities	6,338			5,949			6,220			5,949
Other	1,723			1,749			1,823			1,749
Total deferred credits and other liabilities	26,878			26,575			31,250			26,575
Commitments and Contingencies
Equity
Common stock, $0.001 par value, 2 billion shares authorized; 707 million and 706 million shares outstanding at June 30, 2014 and December 31, 2013, respectively	1			1
Common stock, $0.001 par value, 2 billion shares authorized; 707 million and 706 million shares outstanding at September 30, 2014 and December 31, 2013, respectively							1			1
Additional paid-in capital	39,389			39,365			39,388			39,365
Retained earnings	1,768			2,363			2,479			2,363
Accumulated other comprehensive loss	(355		)	(399		)	(456		)	(399		)
Total Duke Energy Corporation stockholders' equity	40,803			41,330			41,412			41,330
Noncontrolling interests	78			78			41			78
Total equity	40,881			41,408			41,453			41,408
Total Liabilities and Equity	$	115,173		$	114,779		$	119,656		$	114,779

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income	$	520		$	976		$	1,789		$	1,984
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	1,748			1,544			2,641			2,365
Equity component of AFUDC	(61		)	(82		)	(99		)	(121		)
Gains (losses) on sales of other assets	(2		)	8
Community support and charitable contributions expense							—			34
(Gains) losses on sales of other assets							(27		)	8
Impairment charges	1,388			386			848			388
Deferred income taxes	(46		)	397			562			1,014
Equity in earnings of unconsolidated affiliates	(69		)	(58		)	(97		)	(91		)
Accrued pension and other post-retirement benefit costs	54			172			81			259
Contributions to qualified pension plans							—			(27		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	116			40			128			(14		)
Receivables	(118		)	(144		)	(24		)	(154		)
Inventory	122			84			(17		)	119
Other current assets	(451		)	(43		)	(315		)	(48		)
Increase (decrease) in
Accounts payable	(218		)	(308		)	(303		)	(412		)
Taxes accrued	(84		)	95			37			245
Other current liabilities	(308		)	4			(99		)	(31		)
Other assets	(45		)	(175		)	(100		)	(307		)
Other liabilities	73			(53		)	162			(221		)
Net cash provided by operating activities	2,619			2,843			5,167			4,990
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(2,400		)	(2,715		)	(3,755		)	(3,854		)
Investment expenditures	(38		)	(49		)	(65		)	(53		)
Acquisitions	(16		)	—			(16		)	—
Purchases of available-for-sale securities	(1,773		)	(2,827		)	(2,424		)	(4,591		)
Proceeds from sales and maturities of available-for-sale securities	1,793			2,775			2,445			4,687
Net proceeds from the sales of other assets	119			38
Net proceeds from the sales of equity investments and other assets							172			59
Change in restricted cash	(6		)	188			(15		)	166
Other	(46		)	28			(76		)	20
Net cash used in investing activities	(2,367		)	(2,562		)	(3,734		)	(3,566		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	2,088			1,832			2,217			2,993
Issuance of common stock related to employee benefit plans	23			7			24			8
Payments for the:
Redemption of long-term debt	(1,757		)	(1,538		)	(2,503		)	(2,506		)
Redemption of preferred stock of a subsidiary	—			(96		)	—			(96		)
Notes payable and commercial paper	1,024			763			941			537
Distributions to noncontrolling interests	(9		)	(8		)	(45		)	(9		)
Dividends paid	(1,107		)	(1,085		)	(1,670		)	(1,636		)
Other	(7		)	(9		)	33			27
Net cash provided by (used in) financing activities	255			(134		)
Net cash used in financing activities							(1,003		)	(682		)
Net increase in cash and cash equivalents	507			147			430			742
Cash and cash equivalents at beginning of period	1,501			1,424			1,501			1,424
Cash and cash equivalents at end of period	$	2,008		$	1,571		$	1,931		$	2,166
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	348		$	480		$	466		$	383
Dividends declared but not paid	—			551

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CORPORATION

Condensed Consolidated Statements of Changes in Equity

(Unaudited)


									Accumulated Other Comprehensive Loss																													Accumulated Other Comprehensive Loss
(in millions)	Common Stock Shares	Common Stock		Additional Paid-in Capital		Retained Earnings			Foreign Currency Translation Adjustments			Net Gains (Losses) on Cash Flow Hedges			Net Losses on Available-for-Sale Securities			Pension and OPEB Adjustments			Common Stockholders' Equity			Noncontrolling Interests			Total Equity			Common Stock Shares	Common Stock		Additional Paid-in Capital		Retained Earnings			Foreign Currency Translation Adjustments			Net Gains (Losses) on Cash Flow Hedges			Net Gains (Losses) on Available-for-Sale Securities			Pension and OPEB Adjustments			Common Stockholders' Equity			Noncontrolling Interests			Total Equity
Balance at December 31, 2012	704	$	1	$	39,279	$	1,889		$	(116	)	$	(100	)	$	—		$	(90	)	$	40,863		$	78		$	40,941		704	$	1	$	39,279	$	1,889		$	(116	)	$	(100	)	$	—		$	(90	)	$	40,863		$	78		$	40,941
Net income	—	—		—		973			—			—			—			—			973			3			976			—	—		—		1,977			—			—			—			—			1,977			7			1,984
Other comprehensive (loss) income	—	—		—		—			(125		)	54			(4		)	5			(70		)	(4		)	(74		)	—	—		—		—			(133		)	56			(2		)	5			(74		)	(4		)	(78		)
Common stock issuances, including dividend reinvestment and employee benefits	2	—		5		—			—			—			—			—			5			—			5			2	—		38		—			—			—			—			—			38			—			38
Common stock dividends	—	—		—		(1,636		)	—			—			—			—			(1,636		)	—			(1,636		)	—	—		—		(1,636		)	—			—			—			—			(1,636		)	—			(1,636		)
Premium on the redemption of preferred stock of subsidiaries	—	—		—		(3		)	—			—			—			—			(3		)	—			(3		)	—	—		—		(3		)	—			—			—			—			(3		)	—			(3		)
Changes in noncontrolling interest in subsidiaries	—	—		—		—			—			—			—			—			—			(8		)	(8		)	—	—		—		—			—			—			—			—			—			(9		)	(9		)
Balance at June 30, 2013	706	$	1	$	39,284	$	1,223		$	(241	)	$	(46	)	$	(4	)	$	(85	)	$	40,132		$	69		$	40,201
Balance at September 30, 2013																														706	$	1	$	39,317	$	2,227		$	(249	)	$	(44	)	$	(2	)	$	(85	)	$	41,165		$	72		$	41,237

Balance at December 31, 2013	706	$	1	$	39,365	$	2,363		$	(307	)	$	(40	)	$	—		$	(52	)	$	41,330		$	78		$	41,408		706	$	1	$	39,365	$	2,363		$	(307	)	$	(40	)	$	—		$	(52	)	$	41,330		$	78		$	41,408
Net income	—	—		—		512			—			—			—			—			512			8			520			—	—		—		1,786			—			—			—			—			1,786			3			1,789
Other comprehensive income (loss)	—	—		—		—			51			(9		)	2			—			44			1			45
Other comprehensive (loss) income																														—	—		—		—			(55		)	(5		)	2			1			(57		)	5			(52		)
Common stock issuances, including dividend reinvestment and employee benefits	1	—		24		—			—			—			—			—			24			—			24			1	—		23		—			—			—			—			—			23			—			23
Common stock dividends	—	—		—		(1,107		)	—			—			—			—			(1,107		)	—			(1,107		)	—	—		—		(1,670		)	—			—			—			—			(1,670		)	—			(1,670		)
Distribution to noncontrolling interest in subsidiaries	—	—		—		—			—			—			—			—			—			(9		)	(9		)
Balance at June 30, 2014	707	$	1	$	39,389	$	1,768		$	(256	)	$	(49	)	$	2		$	(52	)	$	40,803		$	78		$	40,881
Distributions to noncontrolling interest in subsidiaries																														—	—		—		—			—			—			—			—			—			(45		)	(45		)
Balance at September 30, 2014																														707	$	1	$	39,388	$	2,479		$	(362	)	$	(45	)	$	2		$	(51	)	$	41,412		$	41		$	41,453

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


	Three Months Ended				Six Months Ended				Three Months Ended					Nine Months Ended
	June 30,				June 30,				September 30,					September 30,
(in millions)	2014		2013		2014		2013		2014		2013			2014		2013
Operating Revenues	$	1,755	$	1,591	$	3,755	$	3,320	$	1,938	$	1,919		$	5,693	$	5,239
Operating Expenses
Fuel used in electric generation and purchased power	503		443		1,161		961		524		539			1,685		1,500
Operation, maintenance and other	463		479		950		936		465		456			1,415		1,392
Depreciation and amortization	248		226		490		448		260		228			750		676
Property and other taxes	100		92		204		192		59		90			263		282
Impairment charges	3		—		3		—		—		—			3		—
Total operating expenses	1,317		1,240		2,808		2,537		1,308		1,313			4,116		3,850
Gains on Sales of Other Assets and Other, net	—		—		—		2
Losses on Sales of Other Assets and Other, net									—		(2		)	—		—
Operating Income	438		351		947		785		630		604			1,577		1,389
Other Income and Expenses, net	44		29		93		65		44		29			137		94
Interest Expense	102		91		203		173		104		82			307		255
Income Before Income Taxes	380		289		837		677		570		551			1,407		1,228
Income Tax Expense	110		108		281		252		193		209			474		461
Net Income	$	270	$	181	$	556	$	425	$	377	$	342		$	933	$	767
Other Comprehensive Income, net of tax
Reclassification into earnings from cash flow hedges	1		—		2		—		—		1			2		1
Comprehensive Income	$	271	$	181	$	558	$	425	$	377	$	343		$	935	$	768

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	23		$	23		$	34		$	23
Receivables (net of allowance for doubtful accounts of $3 at June 30, 2014 and December 31, 2013)	163			186
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $6 at June 30, 2014 and December 31, 2013)	705			673
Receivables (net of allowance for doubtful accounts of $3 at September 30, 2014 and December 31, 2013)							123			186
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $6 at September 30, 2014 and December 31, 2013)							695			673
Receivables from affiliated companies	87			75			117			75
Notes receivable from affiliated companies	280			222			339			222
Inventory	909			1,065			973			1,065
Regulatory assets	388			295			388			295
Other	271			309			247			309
Total current assets	2,826			2,848			2,916			2,848
Investments and Other Assets
Nuclear decommissioning trust funds	2,995			2,840			2,965			2,840
Other	997			1,000			975			1,000
Total investments and other assets	3,992			3,840			3,940			3,840
Property, Plant and Equipment
Cost	35,645			34,906			37,670			34,906
Accumulated depreciation and amortization	(12,304		)	(11,894		)	(12,544		)	(11,894		)
Net property, plant and equipment	23,341			23,012			25,126			23,012
Regulatory Assets and Deferred Debits
Regulatory assets	1,509			1,527			1,986			1,527
Other	43			46			42			46
Total regulatory assets and deferred debits	1,552			1,573			2,028			1,573
Total Assets	$	31,711		$	31,273		$	34,010		$	31,273
LIABILITIES AND MEMBER'S EQUITY
Current Liabilities
Accounts payable	$	510		$	701		$	514		$	701
Accounts payable to affiliated companies	156			161			176			161
Taxes accrued	255			147			334			147
Interest accrued	100			97			130			97
Current maturities of long-term debt	47			47			7			47
Regulatory liabilities	30			65			31			65
Other	368			393			399			393
Total current liabilities	1,466			1,611			1,591			1,611
Long-term Debt	8,088			8,089
Long-term Debt Payable to Affiliated Companies	300			300
Long-Term Debt							8,087			8,089
Long-Term Debt Payable to Affiliated Companies							300			300
Deferred Credits and Other Liabilities
Deferred income taxes	5,781			5,706			5,725			5,706
Investment tax credits	207			210			205			210
Accrued pension and other post-retirement benefit costs	157			161			149			161
Asset retirement obligations	1,641			1,594			3,691			1,594
Regulatory liabilities	2,736			2,576			2,690			2,576
Other	678			676			663			676
Total deferred credits and other liabilities	11,200			10,923			13,123			10,923
Commitments and Contingencies
Member's Equity
Member's equity	10,670			10,365			10,922			10,365
Accumulated other comprehensive loss	(13		)	(15		)	(13		)	(15		)
Total member's equity	10,657			10,350			10,909			10,350
Total Liabilities and Member's Equity	$	31,711		$	31,273		$	34,010		$	31,273

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	556		$	425		$	933		$	767
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization (including amortization of nuclear fuel)	621			569			952			865
Equity component of AFUDC	(44		)	(47		)	(68		)	(70		)
Gains on sales of other assets and other, net	—			(2		)
Impairment charge	3			—
Community support and charitable contributions expense							—			14
Impairment charges							3			—
Deferred income taxes	132			247			47			487
Accrued pension and other post-retirement benefit costs	11			20			16			29
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3			(7		)	—			(7		)
Receivables	(39		)	(3		)	5			(24		)
Receivables from affiliated companies	(12		)	(46		)	(42		)	(37		)
Inventory	157			(12		)	91			23
Other current assets	(150		)	(14		)	(130		)	35
Increase (decrease) in
Accounts payable	(107		)	(44		)	(167		)	(90		)
Accounts payable to affiliated companies	(5		)	(6		)	15			107
Taxes accrued	95			(5		)	173			18
Other current liabilities	(57		)	(50		)	7			2
Other assets	6			(68		)	23			(80		)
Other liabilities	15			(41		)	21			(66		)
Net cash provided by operating activities	1,185			916			1,879			1,973
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(851		)	(804		)	(1,289		)	(1,205		)
Purchases of available-for-sale securities	(1,098		)	(1,122		)	(1,533		)	(1,883		)
Proceeds from sales and maturities of available-for-sale securities	1,087			1,098			1,516			1,847
Notes receivable from affiliated companies	(58		)	167			(117		)	(213		)
Other	(14		)	(10		)	(27		)	(11		)
Net cash used in investing activities	(934		)	(671		)	(1,450		)	(1,465		)
CASH FLOWS FROM FINANCING ACTIVITIES
Payments for the redemption of long-term debt							(42		)	—
Distributions to parent	(251		)	(249		)	(376		)	(500		)
Other	—			(2		)	—			(2		)
Net cash used in financing activities	(251		)	(251		)	(418		)	(502		)
Net decrease in cash and cash equivalents	—			(6		)
Net increase in cash and cash equivalents							11			6
Cash and cash equivalents at beginning of period	23			19			23			19
Cash and cash equivalents at end of period	$	23		$	13		$	34		$	25
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	113		$	125		$	177		$	111

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY CAROLINAS, LLC

Condensed Consolidated Statements of Changes in Member's Equity

(Unaudited)


				Accumulated Other Comprehensive Loss												Accumulated Other Comprehensive Loss
(in millions)	Member's Equity			Net Losses on Cash Flow Hedges			Unrealized Losses on Available-for-Sale Securities			Total			Member's Equity			Net (Losses) Gains on Cash Flow Hedges			Unrealized Losses on Available-for-Sale Securities			Total
Balance at December 31, 2012	$	9,888		$	(15	)	$	(1	)	$	9,872		$	9,888		$	(15	)	$	(1	)	$	9,872
Net income	425			—			—			425			767			—			—			767
Other comprehensive income													—			1			—			1
Distributions to parent	(249		)	—			—			(249		)	(500		)	—			—			(500		)
Balance at June 30, 2013	$	10,064		$	(15	)	$	(1	)	$	10,048
Balance at September 30, 2013													$	10,155		$	(14	)	$	(1	)	$	10,140

Balance at December 31, 2013	$	10,365		$	(14	)	$	(1	)	$	10,350		$	10,365		$	(14	)	$	(1	)	$	10,350
Net income	556			—			—			556			933			—			—			933
Other comprehensive income	—			2			—			2			—			2			—			2
Distributions to parent	(251		)	—			—			(251		)	(376		)	—			—			(376		)
Balance at June 30, 2014	$	10,670		$	(12	)	$	(1	)	$	10,657
Balance at September 30, 2014													$	10,922		$	(12	)	$	(1	)	$	10,909

See Notes to Condensed Consolidated Financial Statements

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended					Nine Months Ended
	June 30,						June 30,						September 30,					September 30,
(in millions)	2014			2013			2014			2013			2014		2013			2014			2013
Operating Revenues	$	2,421		$	2,281		$	4,962		$	4,467		$	2,863	$	2,766		$	7,825		$	7,233
Operating Expenses
Fuel used in electric generation and purchased power	977			918			2,020			1,778			1,214		1,154			3,234			2,932
Operation, maintenance and other	555			533			1,150			1,094			564		559			1,714			1,653
Depreciation and amortization	281			210			557			404			294		240			851			644
Property and other taxes	137			141			288			282			127		141			415			423
Impairment charges	(17		)	366			(17		)	366			1		2			(16		)	368
Total operating expenses	1,933			2,168			3,998			3,924			2,200		2,096			6,198			6,020
Gains on Sales of Other Assets and Other, net	—			1			1			1			2		1			3			2
Operating Income	488			114			965			544			665		671			1,630			1,215
Other Income and Expenses, net	13			14			28			37			26		26			54			63
Interest Expense	167			160			336			358			166		162			502			520
Income (Loss) From Continuing Operations Before Taxes	334			(32		)	657			223
Income Tax Expense (Benefit) From Continuing Operations	127			(19		)	246			82
Income (Loss) From Continuing Operations	207			(13		)	411			141
Loss From Discontinued Operations, net of tax	(5		)	(4		)	(6		)	(4		)
Net Income (Loss)	202			(17		)	405			137
Income From Continuing Operations Before Taxes													525		535			1,182			758
Income Tax Expense From Continuing Operations													195		207			441			289
Income From Continuing Operations													330		328			741			469
Income (Loss) From Discontinued Operations, net of tax													—		14			(6		)	10
Net Income													330		342			735			479
Less: Net Income Attributable to Noncontrolling Interest	—			—			1			1			1		1			2			2
Net Income (Loss) Attributable to Parent	$	202		$	(17	)	$	404		$	136
Net Income Attributable to Parent													$	329	$	341		$	733		$	477

Net Income (Loss)	$	202		$	(17	)	$	405		$	137
Net Income													$	330	$	342		$	735		$	479
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	—			—			1			1			1		4			2			5
Net unrealized gain on cash flow hedges	—			2			—			3
Net unrealized loss on cash flow hedges													—		(3		)	—			—
Reclassification into earnings from cash flow hedges	4			—			4			—			1		3			5			3
Unrealized gain on investments in available-for-sale securities													1		—			1			—
Other Comprehensive Income, net of tax	4			2			5			4			3		4			8			8
Comprehensive Income (Loss)	$	206		$	(15	)	$	410		$	141
Comprehensive Income													333		346			743			487
Less: Comprehensive Income Attributable to Noncontrolling Interests													1		1			2			2
Comprehensive Income Attributable to Parent													$	332	$	345		$	741		$	485

See Notes to Condensed Consolidated Financial Statements

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	38		$	58		$	47		$	58
Receivables (net of allowance for doubtful accounts of $7 at June 30, 2014 and $14 at December 31, 2013)	193			528
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $7 at June 30, 2014)	875			417
Receivables (net of allowance for doubtful accounts of $7 at September 30, 2014 and $14 at December 31, 2013)							184			528
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $8 at September 30, 2014)							877			417
Receivables from affiliated companies	19			4			36			4
Notes receivable from affiliated companies	65			75			164			75
Inventory	1,481			1,424			1,509			1,424
Regulatory assets	642			353			566			353
Other	449			726			622			726
Total current assets	3,762			3,585			4,005			3,585
Investments and Other Assets
Nuclear decommissioning trust funds	2,422			2,292			2,409			2,292
Goodwill	3,655			3,655			3,655			3,655
Other	773			804			792			804
Total investments and other assets	6,850			6,751			6,856			6,751
Property, Plant and Equipment
Cost	36,750			36,480			37,796			36,480
Accumulated depreciation and amortization	(13,214		)	(13,098		)	(13,397		)	(13,098		)
Net property, plant and equipment	23,536			23,382			24,399			23,382
Regulatory Assets and Deferred Debits
Regulatory assets	4,036			4,155			4,818			4,155
Other	96			96			94			96
Total regulatory assets and deferred debits	4,132			4,251			4,912			4,251
Total Assets	$	38,280		$	37,969		$	40,172		$	37,969
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	660		$	836		$	636		$	836
Accounts payable to affiliated companies	234			123			265			123
Notes payable to affiliated companies	984			1,213			822			1,213
Taxes accrued	148			105			317			105
Interest accrued	176			181			192			181
Current maturities of long-term debt	318			485			318			485
Regulatory liabilities	87			207			106			207
Other	749			896			743			896
Total current liabilities	3,356			4,046			3,399			4,046
Long-term Debt	14,200			13,630
Long-Term Debt							14,194			13,630
Deferred Credits and Other Liabilities
Deferred income taxes	3,801			3,283			3,999			3,283
Accrued pension and other post-retirement benefit costs	631			765			621			765
Asset retirement obligations	2,597			2,562			4,015			2,562
Regulatory liabilities	2,480			2,292			2,397			2,292
Other	482			527			515			527
Total deferred credits and other liabilities	9,991			9,429			11,547			9,429
Commitments and Contingencies
Common Stockholder's Equity
Common stock, $0.01 par value, 100 shares authorized and outstanding at June 30, 2014 and December 31, 2013	—			—
Common stock, $0.01 par value, 100 shares authorized and outstanding at September 30, 2014 and December 31, 2013							—			—
Additional paid-in capital	7,467			7,467			7,467			7,467
Retained earnings	3,317			3,452			3,647			3,452
Accumulated other comprehensive loss	(54		)	(59		)	(51		)	(59		)
Total common stockholder's equity	10,730			10,860			11,063			10,860
Noncontrolling interests	3			4			(31		)	4
Total equity	10,733			10,864			11,032			10,864
Total Liabilities and Equity	$	38,280		$	37,969
Total Liabilities and Common Stockholder's Equity							$	40,172		$	37,969

See Notes to Condensed Consolidated Financial Statements

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	405		$	137		$	735		$	479
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	642			480			985			764
Equity component of AFUDC	(9		)	(27		)	(18		)	(39		)
Community support and charitable contributions expense							—			20
Losses on sales of other assets	3			4			1			3
Impairment charges	(17		)	366			(16		)	368
Deferred income taxes	261			71			231			384
Accrued pension and other post-retirement benefit costs	14			105			20			158
Contributions to qualified pension plans							—			(27		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	14			23			28			33
Receivables	(166		)	(148		)	(162		)	(219		)
Receivables from affiliated companies	(15		)	12			(32		)	12
Inventory	(18		)	69			(45		)	79
Other current assets	(199		)	(33		)	(147		)	(102		)
Increase (decrease) in
Accounts payable	(41		)	(203		)	(73		)	(227		)
Accounts payable to affiliated companies	111			48			142			25
Taxes accrued	49			124			166			161
Other current liabilities	(157		)	169			(96		)	113
Other assets	(71		)	(126		)	(126		)	(223		)
Other liabilities	(27		)	88			(9		)	(64		)
Net cash provided by operating activities	779			1,159			1,584			1,698
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(888		)	(1,295		)	(1,383		)	(1,739		)
Purchases of available-for-sale securities	(453		)	(978		)	(609		)	(1,651		)
Proceeds from sales and maturities of available-for-sale securities	442			960			594			1,630
Net proceeds from the sales of other assets							2			—
Notes receivable from affiliated companies	10			(101		)	(89		)	(103		)
Other	(41		)	21			(39		)	12
Net cash used in investing activities	(930		)	(1,393		)	(1,524		)	(1,851		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the:
Issuance of long-term debt	875			545			875			545
Payments for the:
Redemption of long-term debt	(473		)	(788		)	(479		)	(1,194		)
Redemption of preferred stock of subsidiary	—			(96		)	—			(96		)
Notes payable to affiliated companies	(229		)	403			(391		)	740
Distributions to noncontrolling interests	(2		)	(2		)	(37		)	(2		)
Other	(40		)	(5		)	(39		)	(5		)
Net cash provided by financing activities	131			57
Net cash used in financing activities							(71		)	(12		)
Net decrease in cash and cash equivalents	(20		)	(177		)	(11		)	(165		)
Cash and cash equivalents at beginning of period	58			231			58			231
Cash and cash equivalents at end of period	$	38		$	54		$	47		$	66
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	156		$	310		$	159		$	199

See Notes to Condensed Consolidated Financial Statements

PART I

PROGRESS ENERGY, INC.

Condensed Consolidated Statements of Changes in Common Stockholder's Equity

(Unaudited)


								Accumulated Other Comprehensive Loss																						Accumulated Other Comprehensive Loss
(in millions)	Common Stock		Additional Paid-in Capital		Retained Earnings			Net Losses on Cash Flow Hedges			Pension and OPEB Related Adjustments			Common Stockholder's Equity			Noncontrolling Interests			Total Equity			Common Stock		Additional Paid-in Capital		Retained Earnings			Net Gains (Losses) on Cash Flow Hedges			Net Gains on Available for Sale Securities		Pension and OPEB Related Adjustments			Common Stockholder's Equity			Noncontrolling Interests			Total Equity
Balance at December 31, 2012	$	—	$	7,465	$	2,783		$	(42	)	$	(25	)	$	10,181		$	4		$	10,185		$	—	$	7,465	$	2,783		$	(42	)	$	—	$	(25	)	$	10,181		$	4		$	10,185
Net income	—		—		136			—			—			136			1			137			—		—		477			—			—		—			477			2			479
Other comprehensive income	—		—		—			3			1			4			—			4			—		—		—			3			—		5			8			—			8
Premium on the redemption of preferred stock of subsidiaries	—		—		(3		)	—			—			(3		)	—			(3		)	—		—		(3		)	—			—		—			(3		)	—			(3		)
Distributions to noncontrolling interests	—		—		—			—			—			—			(2		)	(2		)	—		—		—			—			—		—			—			(2		)	(2		)
Balance at June 30, 2013	$	—	$	7,465	$	2,916		$	(39	)	$	(24	)	$	10,318		$	3		$	10,321
Balance at September 30, 2013																							$	—	$	7,465	$	3,257		$	(39	)	$	—	$	(20	)	$	10,663		$	4		$	10,667

Balance at December 31, 2013	$	—	$	7,467	$	3,452		$	(43	)	$	(16	)	$	10,860		$	4		$	10,864		$	—	$	7,467	$	3,452		$	(43	)	$	—	$	(16	)	$	10,860		$	4		$	10,864
Net income	—		—		404			—			—			404			1			405			—		—		733			—					—			733			2			735
Other comprehensive income	—		—		—			4			1			5			—			5			—		—		—			5			1		2			8			—			8
Distributions to noncontrolling interests	—		—		—			—			—			—			(2		)	(2		)	—		—		—			—			—		—			—			(37		)	(37		)
Transfer of service company net assets to Duke Energy	—		—		(539		)	—			—			(539		)	—			(539		)	—		—		(538		)	—			—		—			(538		)	—			(538		)
Balance at June 30, 2014	$	—	$	7,467	$	3,317		$	(39	)	$	(15	)	$	10,730		$	3		$	10,733
Balance at September 30, 2014																							$	—	$	7,467	$	3,647		$	(38	)	$	1	$	(14	)	$	11,063		$	(31	)	$	11,032

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY PROGRESS, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


	Three Months Ended					Six Months Ended					Three Months Ended				Nine Months Ended
	June 30,					June 30,					September 30,				September 30,
(in millions)	2014			2013		2014			2013		2014		2013		2014			2013
Operating Revenues	$	1,191		$	1,135	$	2,613		$	2,351	$	1,367	$	1,430	$	3,980		$	3,781
Operating Expenses
Fuel used in electric generation and purchased power	454			441		1,027			896		552		574		1,579			1,470
Operation, maintenance and other	347			340		728			692		346		352		1,074			1,044
Depreciation and amortization	142			113		286			250		155		143		441			393
Property and other taxes	54			53		121			113		29		59		150			172
Impairment charges	(18		)	22		(18		)	22		—		—		(18		)	22
Total operating expenses	979			969		2,144			1,973		1,082		1,128		3,226			3,101
Gains on Sales of Other Assets and Other, net	—			—		1			—		—		1		1			1
Operating Income	212			166		470			378		285		303		755			681
Other Income and Expenses, net	7			8		16			22		18		21		34			43
Interest Expense	58			47		115			95		57		52		172			147
Income Before Income Taxes	161			127		371			305		246		272		617			577
Income Tax Expense	60			50		137			118		89		97		226			215
Net Income and Comprehensive Income	$	101		$	77	$	234		$	187	$	157	$	175	$	391		$	362

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY PROGRESS, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	7		$	21		$	6		$	21
Receivables (net of allowance for doubtful accounts of $6 at June 30, 2014 and $10 at December 31, 2013)	120			145
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $5 at June 30, 2014)	471			417
Receivables (net of allowance for doubtful accounts of $6 at September 30, 2014 and $10 at December 31, 2013)							72			145
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $5 at September 30, 2014)							475			417
Receivables from affiliated companies	6			2			9			2
Inventory	897			853			928			853
Regulatory assets	369			127			325			127
Other	271			296			261			296
Total current assets	2,141			1,861			2,076			1,861
Investments and Other Assets
Nuclear decommissioning trust funds	1,632			1,539			1,626			1,539
Other	461			443			475			443
Total investments and other assets	2,093			1,982			2,101			1,982
Property, Plant and Equipment
Cost	22,638			22,273			23,511			22,273
Accumulated depreciation and amortization	(8,828		)	(8,623		)	(8,931		)	(8,623		)
Net property, plant and equipment	13,810			13,650			14,580			13,650
Regulatory Assets and Deferred Debits
Regulatory assets	1,428			1,384			2,187			1,384
Other	34			32			34			32
Total regulatory assets and deferred debits	1,462			1,416			2,221			1,416
Total Assets	$	19,506		$	18,909		$	20,978		$	18,909
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	316		$	420		$	305		$	420
Accounts payable to affiliated companies	162			103			205			103
Notes payable to affiliated companies	201			462			122			462
Taxes accrued	48			37			149			37
Interest accrued	78			70			78			70
Current maturities of long-term debt	306			174			306			174
Regulatory liabilities	61			63			66			63
Other	329			392			344			392
Total current liabilities	1,501			1,721			1,575			1,721
Long-term Debt	5,411			5,061
Long-Term Debt							5,410			5,061
Deferred Credits and Other Liabilities
Deferred income taxes	2,715			2,557			2,729			2,557
Accrued pension and other post-retirement benefit costs	315			321			311			321
Asset retirement obligations	1,779			1,729			3,206			1,729
Regulatory liabilities	1,853			1,673			1,796			1,673
Other	198			222			159			222
Total deferred credits and other liabilities	6,860			6,502			8,201			6,502
Commitments and Contingencies
Common Stockholder's Equity
Common stock, no par value, 200 million shares authorized; 160 million shares outstanding at June 30, 2014 and December 31, 2013	2,159			2,159
Common stock, no par value, 200 million shares authorized; 160 million shares outstanding at September 30, 2014 and December 31, 2013							2,159			2,159
Retained earnings	3,575			3,466			3,633			3,466
Total common stockholder's equity	5,734			5,625			5,792			5,625
Total Liabilities and Common Stockholder's Equity	$	19,506		$	18,909		$	20,978		$	18,909

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY PROGRESS, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	234		$	187		$	391		$	362
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion (including amortization of nuclear fuel)	368			324			570			507
Equity component of AFUDC	(9		)	(23		)	(17		)	(33		)
Community support and charitable contributions expense							—			20
Gains on sales of other assets and other, net	(1		)	—			(1		)	(1		)
Impairment charges	(18		)	22			(18		)	22
Deferred income taxes	156			146			152			272
Accrued pension and other post-retirement benefit costs	(4		)	48			(5		)	74
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	7			(12		)	9			(11		)
Receivables	(8		)	(49		)	33			(75		)
Receivables from affiliated companies	(4		)	(3		)	(7		)	4
Inventory	(22		)	23			(53		)	32
Other current assets	(151		)	(69		)	(97		)	(41		)
Increase (decrease) in
Accounts payable	(61		)	(142		)	(67		)	(168		)
Accounts payable to affiliated companies	59			27			102			—
Taxes accrued	11			41			95			63
Other current liabilities	(52		)	(49		)	(46		)	(75		)
Other assets	(13		)	(53		)	(28		)	(87		)
Other liabilities	(7		)	5			(23		)	(77		)
Net cash provided by operating activities	485			423			990			788
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(540		)	(725		)	(871		)	(998		)
Purchases of available-for-sale securities	(269		)	(318		)	(371		)	(460		)
Proceeds from sales and maturities of available-for-sale securities	253			299			351			438
Other	(34		)	3			(25		)	3
Net cash used in investing activities	(590		)	(741		)	(916		)	(1,017		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	650			545			650			545
Payments for the:
Redemption of long-term debt	(168		)	(50		)	(169		)	(451		)
Redemption of preferred stock of subsidiary	—			(62		)	—			(62		)
Notes payable to affiliated companies	(261		)	(107		)	(340		)	217
Dividends to parent	(125		)	—			(224		)	—
Other	(5		)	(6		)	(6		)	(6		)
Net cash provided by financing activities	91			320
Net cash (used in) provided by financing activities							(89		)	243
Net (decrease) increase in cash and cash equivalents	(14		)	2			(15		)	14
Cash and cash equivalents at beginning of period	21			18			21			18
Cash and cash equivalents at end of period	$	7		$	20		$	6		$	32
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	113		$	216		$	107		$	122

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY PROGRESS, INC.

Condensed Consolidated Statements of Changes in Common Stockholder's Equity

(Unaudited)


(in millions)	Common Stock		Retained Earnings			Total Equity			Common Stock		Retained Earnings			Total Equity
Balance at December 31, 2012	$	2,159	$	2,968		$	5,127		$	2,159	$	2,968		$	5,127
Net income	—		187			187			—		362			362
Premium on the redemption of preferred stock	—		(2		)	(2		)	—		(2		)	(2		)
Balance at June 30, 2013	$	2,159	$	3,153		$	5,312
Balance at September 30, 2013									$	2,159	$	3,328		$	5,487

Balance at December 31, 2013	$	2,159	$	3,466		$	5,625		$	2,159	$	3,466		$	5,625
Net income	—		234			234			—		391			391
Dividends to parent	—		(125		)	(125		)	—		(224		)	(224		)
Balance at June 30, 2014	$	2,159	$	3,575		$	5,734
Balance at September 30, 2014									$	2,159	$	3,633		$	5,792

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY FLORIDA, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


	Three Months Ended					Six Months Ended				Three Months Ended					Nine Months Ended
	June 30,					June 30,				September 30,					September 30,
(in millions)	2014		2013			2014		2013		2014		2013			2014		2013
Operating Revenues	$	1,225	$	1,142		$	2,341	$	2,110	$	1,491	$	1,332		$	3,832	$	3,442
Operating Expenses
Fuel used in electric generation and purchased power	523		478			993		883		662		579			1,655		1,462
Operation, maintenance and other	204		198			414		409		212		207			626		616
Depreciation and amortization	139		90			271		142		139		95			410		237
Property and other taxes	83		85			167		164		99		81			266		245
Impairment charges	—		345			1		345		1		1			2		346
Total operating expenses	949		1,196			1,846		1,943		1,113		963			2,959		2,906
Gains on Sales of Other Assets and Other, net	—		1			—		1		—		—			—		1
Operating Income (Loss)	276		(53		)	495		168
Operating Income										378		369			873		537
Other Income and Expenses, net	6		5			11		13		6		6			17		19
Interest Expense	50		43			99		92		51		46			150		138
Income (Loss) Before Income Taxes	232		(91		)	407		89
Income Tax Expense (Benefit)	90		(34		)	157		36
Net Income (Loss)	$	142	$	(57	)	$	250	$	53
Other Comprehensive Income, net of tax
Income Before Income Taxes										333		329			740		418
Income Tax Expense										128		132			285		168
Net Income										$	205	$	197		$	455	$	250
Other Comprehensive Income (Loss), net of tax
Pension and OPEB adjustments										—		$	(1	)	—		$	(1	)
Reclassification into earnings from cash flow hedges	—		—			1		—		—		—			1		—
Comprehensive Income (Loss)	$	142	$	(57	)	$	251	$	53
Other Comprehensive Income (Loss), net of tax										$	—	$	(1	)	$	1	$	(1	)
Comprehensive Income										$	205	$	196		$	456	$	249

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY FLORIDA, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	13		$	16		$	15		$	16
Receivables (net of allowance for doubtful accounts of $2 at June 30, 2014 and $4 at December 31, 2013)	71			375
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $3 at June 30, 2014)	403			—
Receivables (net of allowance for doubtful accounts of $2 at September 30, 2014 and $4 at December 31, 2013)							109			375
Restricted receivables of variable interest entities (net of allowance for doubtful accounts of $3 at September 30, 2014)							403			—
Receivables from affiliated companies	7			3			40			3
Notes receivable from affiliated companies	76			—			182			—
Inventory	583			571			581			571
Regulatory assets	273			221			241			221
Other	23			182			230			182
Total current assets	1,449			1,368			1,801			1,368
Investments and Other Assets
Nuclear decommissioning trust funds	790			753			783			753
Other	256			252			261			252
Total investments and other assets	1,046			1,005			1,044			1,005
Property, Plant and Equipment
Cost	14,102			13,863			14,275			13,863
Accumulated depreciation and amortization	(4,380		)	(4,252		)	(4,460		)	(4,252		)
Net property, plant and equipment	9,722			9,611			9,815			9,611
Regulatory Assets and Deferred Debits
Regulatory assets	2,609			2,729			2,631			2,729
Other	43			44			42			44
Total regulatory assets and deferred debits	2,652			2,773			2,673			2,773
Total Assets	$	14,869		$	14,757		$	15,333		$	14,757
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	345		$	333		$	331		$	333
Accounts payable to affiliated companies	67			38			67			38
Notes payable to affiliated companies	—			181			—			181
Taxes accrued	173			66			164			66
Interest accrued	42			46			65			46
Current maturities of long-term debt	12			11			12			11
Regulatory liabilities	26			144			40			144
Other	405			445			370			445
Total current liabilities	1,070			1,264			1,049			1,264
Long-term Debt	5,095			4,875
Long-Term Debt							5,090			4,875
Deferred Credits and Other Liabilities
Deferred income taxes	1,800			1,829			2,109			1,829
Accrued pension and other post-retirement benefit costs	283			286			277			286
Asset retirement obligations	818			833			809			833
Regulatory liabilities	625			618			600			618
Other	254			255			270			255
Total deferred credits and other liabilities	3,780			3,821			4,065			3,821
Commitments and Contingencies
Common Stockholder's Equity
Common Stock, no par; 60 million shares authorized; 100 shares outstanding at June 30, 2014 and December 31, 2013	1,762			1,762
Common Stock, no par; 60 million shares authorized; 100 shares outstanding at September 30, 2014 and December 31, 2013							1,762			1,762
Retained earnings	3,162			3,036			3,367			3,036
Accumulated other comprehensive loss	—			(1		)	—			(1		)
Total common stockholder's equity	4,924			4,797			5,129			4,797
Total Liabilities and Common Stockholder's Equity	$	14,869		$	14,757		$	15,333		$	14,757

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY FLORIDA, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	250		$	53		$	455		$	250
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, amortization and accretion	273			145			413			240
Equity component of AFUDC	—			(4		)	(1		)	(6		)
Gains on sales of other assets and other, net	—			(1		)	—			(1		)
Impairment charges	1			345			2			346
Deferred income taxes	84			34			194			229
Accrued pension and other post-retirement benefit costs	15			43			22			66
Contributions to qualified pension plans							—			(27		)
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	3			33			13			37
Receivables	(82		)	(85		)	(118		)	(127		)
Receivables from affiliated companies	(4		)	20			(37		)	19
Inventory	4			44			7			46
Other current assets	(49		)	(44		)	(90		)	(132		)
Increase (decrease) in
Accounts payable	58			26			32			30
Accounts payable to affiliated companies	29			(3		)	29			(19		)
Taxes accrued	108			127			68			152
Other current liabilities	(94		)	232			(50		)	203
Other assets	(58		)	(76		)	(92		)	(128		)
Other liabilities	(29		)	23			(53		)	(44		)
Net cash provided by operating activities	509			912			794			1,134
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(348		)	(564		)	(513		)	(734		)
Purchases of available-for-sale securities	(183		)	(661		)	(238		)	(1,191		)
Proceeds from sales and maturities of available-for-sale securities	188			661			243			1,192
Notes receivable from affiliated companies	(76		)	207			(182		)	177
Other	(8		)	9			(14		)	—
Net cash used in investing activities	(427		)	(348		)	(704		)	(556		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt	225			—			225			—
Payments for the:
Redemption of long-term debt	(4		)	(429		)	(10		)	(435		)
Redemption of preferred stock	—			(34		)	—			(34		)
Notes payable to affiliated companies	(181		)	11			(181		)	—
Dividends to parent	(124		)	(225		)	(124		)	(225		)
Other	(1		)	—			(1		)	—
Net cash used in financing activities	(85		)	(677		)	(91		)	(694		)
Net decrease in cash and cash equivalents	(3		)	(113		)	(1		)	(116		)
Cash and cash equivalents at beginning of period	16			131			16			131
Cash and cash equivalents at end of period	$	13		$	18		$	15		$	15
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	44		$	93		$	52		$	76

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY FLORIDA, INC.

Condensed Consolidated Statements of Changes in Common Stockholder's Equity

(Unaudited)


						Accumulated Other Comprehensive Income											Accumulated Other Comprehensive Income
(in millions)	Common Stock		Retained Earnings			Net Gain (Loss) on Cash Flow Hedges			Total			Common Stock		Retained Earnings			Net Gain (Loss) on Cash Flow Hedges			Pension and OPEB Related Adjustments			Total
Balance at December 31, 2012	$	1,762	$	3,037		$	—		$	4,799		$	1,762	$	3,037		$	—		$	—		$	4,799
Net income	—		53			—			53			—		250			—			—			250
Other comprehensive loss												—		—			—			(1		)	(1		)
Dividends to parent	—		(225		)	—			(225		)	—		(225		)	—			—			(225		)
Premium on the redemption of preferred stock	—		(1		)	—			(1		)	—		(1		)	—			—			(1		)
Balance at June 30, 2013	$	1,762	$	2,864		$	—		$	4,626
Balance at September 30, 2013												$	1,762	$	3,061		$	—		$	(1	)	$	4,822

Balance at December 31, 2013	$	1,762	$	3,036		$	(1	)	$	4,797		$	1,762	$	3,036		$	(1	)	$	—		$	4,797
Net income	—		250			—			250			—		455			—			—			455
Other comprehensive income	—		—			1			1			—		—			1			—			1
Dividends to parent	—		(124		)	—			(124		)	—		(124		)	—			—			(124		)
Balance at June 30, 2014	$	1,762	$	3,162		$	—		$	4,924
Balance at September 30, 2014												$	1,762	$	3,367		$	—		$	—		$	5,129

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


	Three Months Ended					Six Months Ended					Three Months Ended				Nine Months Ended
	June 30,					June 30,					September 30,				September 30,
(in millions)	2014			2013		2014			2013		2014		2013		2014			2013
Operating Revenues
Regulated electric	$	336		$	339	$	703		$	672	$	352	$	338	$	998		$	957
Nonregulated electric and other	88			378		261			606		6		16		17			28
Regulated natural gas	107			94		330			280		88		84		418			364
Total operating revenues	531			811		1,294			1,558		446		438		1,433			1,349
Operating Expenses
Fuel used in electric generation and purchased power - regulated	107			103		231			206		129		121		360			327
Fuel used in electric generation and purchased power - nonregulated	226			222		357			462		5		13		24			32
Cost of natural gas	25			17		127			93		8		9		129			102
Operation, maintenance and other	186			212		367			397		134		133		378			415
Depreciation and amortization	56			89		147			177		54		53		167			160
Property and other taxes	52			64		127			136		58		59		170			184
Impairment charges	21			—		1,438			—		—		—		94			—
Total operating expenses	673			707		2,794			1,471		388		388		1,322			1,220
Gains on Sales of Other Assets and Other, net	—			4		—			4		—		—		—			4
Operating (Loss) Income	(142		)	108		(1,500		)	91
Operating Income											58		50		111			133
Other Income and Expenses, net	2			1		5			3		3		2		9			4
Interest Expense	29			18		51			36		20		14		60			47
(Loss) Income Before Income Taxes	(169		)	91		(1,546		)	58
Income Tax (Benefit) Expense	(62		)	33		(549		)	21
Net (Loss) Income	$	(107	)	$	58	$	(997	)	$	37
Income From Continuing Operations Before Income Taxes											41		38		60			90
Income Tax Expense From Continuing Operations											15		14		21			33
Income From Continuing Operations											$	26	$	24	$	39		$	57
Income (Loss) From Discontinued Operations, net of tax											413		35		(597		)	39
Net Income (Loss)											$	439	$	59	$	(558	)	$	96
Other Comprehensive Income, net of tax
Pension and OPEB adjustments	—			—		—			1		—		—		—			1
Comprehensive (Loss) Income	$	(107	)	$	58	$	(997	)	$	38
Comprehensive Income (Loss)											$	439	$	59	$	(558	)	$	97

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	25		$	36		$	28		$	36
Receivables (net of allowance for doubtful accounts of $2 at June 30, 2014 and December 31, 2013)	119			121
Receivables (net of allowance for doubtful accounts of $1 at September 30, 2014 and $2 at December 31, 2013)							110			121
Receivables from affiliated companies	73			121			59			121
Notes receivable from affiliated companies	184			57			235			57
Inventory	120			229			139			229
Assets held for sale	359			—			284			—
Regulatory assets	71			57			67			57
Other	188			270			135			270
Total current assets	1,139			891			1,057			891
Investments and Other Assets
Goodwill	920			920			920			920
Assets held for sale	2,153			—			2,682			—
Other	19			232			20			232
Total investments and other assets	3,092			1,152			3,622			1,152
Property, Plant and Equipment
Cost	7,091			11,143			7,155			11,143
Accumulated depreciation and amortization	(2,223		)	(2,908		)	(2,250		)	(2,908		)
Net property, plant and equipment	4,868			8,235			4,905			8,235
Regulatory Assets and Deferred Debits
Regulatory assets	461			471			480			471
Other	9			14			8			14
Total regulatory assets and deferred debits	470			485			488			485
Total Assets	$	9,569		$	10,763		$	10,072		$	10,763
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	166		$	319		$	168		$	319
Accounts payable to affiliated companies	74			77			71			77
Notes payable to affiliated companies	828			43			563			43
Taxes accrued	97			167			188			167
Interest accrued	20			17			30			17
Current maturities of long-term debt	197			47			197			47
Liabilities associated with assets held for sale	257			—			269			—
Regulatory liabilities	13			27			10			27
Other	78			110			79			110
Total current liabilities	1,730			807			1,575			807
Long-term Debt	1,587			2,141
Long-Term Debt							1,586			2,141
Deferred Credits and Other Liabilities
Deferred income taxes	1,527			2,012			1,753			2,012
Accrued pension and other post-retirement benefit costs	31			58			29			58
Liabilities associated with assets held for sale	74			—			57			—
Asset retirement obligations	25			28			25			28
Regulatory liabilities	261			262			267			262
Other	162			186			169			186
Total deferred credits and other liabilities	2,080			2,546			2,300			2,546
Commitments and Contingencies
Common Stockholder's Equity
Common stock, $8.50 par value, 120,000,000 shares authorized; 89,663,086 shares outstanding at June 30, 2014 and December 31, 2013	762			762
Common stock, $8.50 par value, 120,000,000 shares authorized; 89,663,086 shares outstanding at September 30, 2014 and December 31, 2013							762			762
Additional paid-in capital	4,782			4,882			4,782			4,882
Accumulated deficit	(1,372		)	(375		)	(933		)	(375		)
Total common stockholder's equity	4,172			5,269			4,611			5,269
Total Liabilities and Common Stockholder's Equity	$	9,569		$	10,763		$	10,072		$	10,763

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$	(997	)	$	37		$	(558	)	$	96
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation and amortization	154			179			205			268
Equity component of AFUDC	(2		)	—			(3		)	—
Gains on sales of other assets and other, net	—			(4		)	—			(5		)
Impairment charges	1,438			—			889			—
Deferred income taxes	(513		)	15			(285		)	76
Accrued pension and other post-retirement benefit costs	4			9			6			12
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions	139			22			124			—
Receivables	(98		)	(19		)	(66		)	(6		)
Receivables from affiliated companies	48			(8		)	62			1
Inventory	(4		)	21			(16		)	29
Other current assets	(30		)	(19		)	56			(8		)
Increase (decrease) in
Accounts payable	(6		)	(36		)	(42		)	(56		)
Accounts payable to affiliated companies	(3		)	(4		)	(6		)	4
Taxes accrued	(74		)	(49		)	13			(29		)
Other current liabilities	(9		)	(2		)	46			10
Other assets	(36		)	(9		)	(8		)	3
Other liabilities	(8		)	(23		)	(20		)	(63		)
Net cash provided by operating activities	3			110			397			332
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(167		)	(222		)	(242		)	(318		)
Net proceeds from the sales of other assets	—			11			—			11
Notes receivable from affiliated companies	(127		)	(18		)	(178		)	(45		)
Other							—			1
Net cash used in investing activities	(294		)	(229		)	(420		)	(351		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt							—			450
Payments for the redemption of long-term debt	(405		)	(253		)	(406		)	(257		)
Notes payable to affiliated companies	785			357			520			(176		)
Dividends to parent	(100		)	—			(100		)	—
Other	—			(1		)	1			(2		)
Net cash provided by financing activities	280			103			15			15
Net decrease in cash and cash equivalents	(11		)	(16		)	(8		)	(4		)
Cash and cash equivalents at beginning of period	36			31			36			31
Cash and cash equivalents at end of period	$	25		$	15		$	28		$	27
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	19		$	18		$	21		$	20

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY OHIO, INC.

Condensed Consolidated Statements of Changes in Common Stockholder's Equity

(Unaudited)


									Accumulated Other Comprehensive (Loss) Income														Accumulated Other Comprehensive (Loss) Income
(in millions)	Common Stock		Additional Paid-in Capital			Accumulated Deficit			Pension and OPEB Related Adjustments			Total			Common Stock		Additional Paid-in Capital			Accumulated Deficit			Pension and OPEB Related Adjustments			Total
Balance at December 31, 2012	$	762	$	4,882		$	(477	)	$	(1	)	$	5,166		$	762	$	4,882		$	(477	)	$	(1	)	$	5,166
Net income	—		—			37			—			37			—		—			96			—			96
Other comprehensive income	—		—			—			1			1			—		—			—			1			1
Balance at June 30, 2013	$	762	$	4,882		$	(440	)	$	—		$	5,204
Balance at September 30, 2013															$	762	$	4,882		$	(381	)	$	—		$	5,263

Balance at December 31, 2013	$	762	$	4,882		$	(375	)	$	—		$	5,269		$	762	$	4,882		$	(375	)	$	—		$	5,269
Net loss	—		—			(997		)	—			(997		)	—		—			(558		)	—			(558		)
Dividends to parent	—		(100		)	—			—			(100		)	—		(100		)	—			—			(100		)
Balance at June 30, 2014	$	762	$	4,782		$	(1,372	)	$	—		$	4,172
Balance at September 30, 2014															$	762	$	4,782		$	(933	)	$	—		$	4,611

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY INDIANA, INC.

Condensed Consolidated Statements of Operations and Comprehensive Income

(Unaudited)


	Three Months Ended					Six Months Ended					Three Months Ended					Nine Months Ended
	June 30,					June 30,					September 30,					September 30,
(in millions)	2014		2013			2014		2013			2014		2013			2014		2013
Operating Revenues	$	748	$	700		$	1,593	$	1,424		$	790	$	755		$	2,383	$	2,179
Operating Expenses
Fuel used in electric generation and purchased power	287		276			626		569			319		283			945		852
Operation, maintenance and other	159		163			325		313			160		176			485		489
Depreciation and amortization	103		77			205		155			104		72			309		227
Property and other taxes	21		16			44		38			25		21			69		59
Total operating expenses	570		532			1,200		1,075			608		552			1,808		1,627
Operating Income	178		168			393		349			182		203			575		552
Other Income and Expenses, net	4		6			11		10			5		4			16		14
Interest Expense	44		43			87		84			40		43			127		127
Income Before Income Taxes	138		131			317		275			147		164			464		439
Income Tax Expense	51		49			117		103			46		60			163		163
Net Income	$	87	$	82		$	200	$	172		$	101	$	104		$	301	$	276
Other Comprehensive Loss, net of tax
Pension and OPEB adjustments	—		(1		)	—		(1		)
Reclassification into earnings from cash flow hedges											—		(1		)	—		(2		)
Comprehensive Income	$	87	$	81		$	200	$	171		$	101	$	103		$	301	$	274

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY INDIANA, INC.

Condensed Consolidated Balance Sheets

(Unaudited)


(in millions)	June 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
ASSETS
Current Assets
Cash and cash equivalents	$	12		$	15		$	24		$	15
Receivables (net of allowance for doubtful accounts of $1 at June 30, 2014 and December 31, 2013)	42			22
Receivables (net of allowance for doubtful accounts of $1 at September 30, 2014 and December 31, 2013)							54			22
Receivables from affiliated companies	108			151			79			151
Notes receivable from affiliated companies	75			96			—			96
Inventory	440			434			464			434
Regulatory assets	173			118			134			118
Other	231			125			235			125
Total current assets	1,081			961			990			961
Investments and Other Assets
Other	218			269			214			269
Total investments and other assets	218			269			214			269
Property, Plant and Equipment
Cost	12,717			12,489			12,918			12,489
Accumulated depreciation and amortization	(4,049		)	(3,913		)	(4,138		)	(3,913		)
Net property, plant and equipment	8,668			8,576			8,780			8,576
Regulatory Assets and Deferred Debits
Regulatory assets	669			717			670			717
Other	25			25			24			25
Total regulatory assets and deferred debits	694			742			694			742
Total Assets	$	10,661		$	10,548		$	10,678		$	10,548
LIABILITIES AND COMMON STOCKHOLDER'S EQUITY
Current Liabilities
Accounts payable	$	129		$	206		$	152		$	206
Accounts payable to affiliated companies	69			56			60			56
Notes payable to affiliated companies							61			—
Taxes accrued	138			57			51			57
Interest accrued	59			56			53			56
Current maturities of long-term debt	5			5			5			5
Regulatory liabilities	10			16			28			16
Other	125			88			116			88
Total current liabilities	535			484			526			484
Long-term Debt	3,640			3,641
Long-term Debt Payable to Affiliated Companies	150			150
Long-Term Debt							3,640			3,641
Long-Term Debt Payable to Affiliated Companies							150			150
Deferred Credits and Other Liabilities
Deferred income taxes	1,303			1,171			1,441			1,171
Investment tax credits	140			140			139			140
Accrued pension and other post-retirement benefit costs	106			163			104			163
Asset retirement obligations	30			30			30			30
Regulatory liabilities	804			782			811			782
Other	39			48			48			48
Total deferred credits and other liabilities	2,422			2,334			2,573			2,334
Commitments and Contingencies
Common Stockholder's Equity
Common Stock, no par; $0.01 stated value, 60,000,000 shares authorized; 53,913,701 shares outstanding at June 30, 2014 and December 31, 2013	1			1
Common Stock, no par; $0.01 stated value, 60,000,000 shares authorized; 53,913,701 shares outstanding at September 30, 2014 and December 31, 2013							1			1
Additional paid-in capital	1,384			1,384			1,384			1,384
Retained earnings	2,526			2,551			2,401			2,551
Accumulated other comprehensive income	3			3			3			3
Total common stockholder's equity	3,914			3,939			3,789			3,939
Total Liabilities and Common Stockholder's Equity	$	10,661		$	10,548		$	10,678		$	10,548

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY INDIANA, INC.

Condensed Consolidated Statements of Cash Flows

(Unaudited)


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$	200		$	172		$	301		$	276
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	206			158			311			230
Equity component of AFUDC	(6		)	(7		)	(10		)	(11		)
Deferred income taxes	45			92			136			190
Accrued pension and other post-retirement benefit costs	7			12			12			19
(Increase) decrease in
Net realized and unrealized mark-to-market and hedging transactions							—			(31		)
Receivables	(19		)	(2		)	(20		)	15
Receivables from affiliated companies	43			(6		)	72			(19		)
Inventory	(6		)	(17		)	(30		)	(33		)
Other current assets	(16		)	(1		)	40			27
Increase (decrease) in
Accounts payable	(47		)	(7		)	(44		)	(22		)
Accounts payable to affiliated companies	13			(13		)	4			(7		)
Taxes accrued	51			(8		)	(36		)	16
Other current liabilities	(4		)	(10		)	3			(9		)
Other assets	(8		)	11			(15		)	2
Other liabilities	35			(18		)	44			(78		)
Net cash provided by operating activities	494			356			768			565
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures	(291		)	(281		)	(462		)	(387		)
Purchases of available-for-sale securities	(9		)	(5		)	(17		)	(7		)
Proceeds from sales and maturities of available-for-sale securities	6			5			13			6
Notes receivable from affiliated companies	21			(21		)	96			(69		)
Other	3			1			4			(4		)
Net cash used in investing activities	(270		)	(301		)	(366		)	(461		)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from the issuance of long-term debt							—			498
Payments for the redemption of long-term debt	(1		)	(1		)	(2		)	(403		)
Notes payable to affiliated companies	—			(81		)	61			(81		)
Dividends to parent	(225		)	—			(451		)	(125		)
Other	(1		)	(1		)	(1		)	(4		)
Net cash used in financing activities	(227		)	(83		)	(393		)	(115		)
Net decrease in cash and cash equivalents	(3		)	(28		)
Net increase (decrease) in cash and cash equivalents							9			(11		)
Cash and cash equivalents at beginning of period	15			36			15			36
Cash and cash equivalents at end of period	$	12		$	8		$	24		$	25
Supplemental Disclosures:
Significant non-cash transactions:
Accrued capital expenditures	$	43		$	32		$	64		$	36

See Notes to Condensed Consolidated Financial Statements

PART I

DUKE ENERGY INDIANA, INC.

Condensed Consolidated Statements of Changes in Common Stockholder's Equity

(Unaudited)


								Accumulated Other Comprehensive Income													Accumulated Other Comprehensive Income
(in millions)	Common Stock		Additional Paid-in Capital		Retained Earnings			Net Gains on Cash Flow Hedges			Total			Common Stock		Additional Paid-in Capital		Retained Earnings			Net Gains (Losses) on Cash Flow Hedges			Total
Balance at December 31, 2012	$	1	$	1,384	$	2,318		$	5		$	3,708		$	1	$	1,384	$	2,318		$	5		$	3,708
Net income	—		—		172			—			172			—		—		276			—			276
Other comprehensive loss	—		—		—			(1		)	(1		)	—		—		—			(2		)	(2		)
Balance at June 30, 2013	$	1	$	1,384	$	2,490		$	4		$	3,879
Dividends to parent														—		—		(125		)	—			(125		)
Balance at September 30, 2013														$	1	$	1,384	$	2,469		$	3		$	3,857

Balance at December 31, 2013	$	1	$	1,384	$	2,551		$	3		$	3,939		$	1	$	1,384	$	2,551		$	3		$	3,939
Net income	—		—		200			—			200			—		—		301			—			301
Dividends to parent	—		—		(225		)	—			(225		)	—		—		(451		)	—			(451		)
Balance at June 30, 2014	$	1	$	1,384	$	2,526		$	3		$	3,914
Balance at September 30, 2014														$	1	$	1,384	$	2,401		$	3		$	3,789

See Notes to Condensed Consolidated Financial Statements

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements

(Unaudited)

Index to Combined Notes To Condensed Consolidated Financial Statements

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

Applicable Notes

Registrant

Duke Energy Corporation

•

Duke Energy Carolinas, LLC

•

Progress Energy, Inc.

•

Duke Energy Progress, Inc.

•

Duke Energy Florida, Inc.

•

Duke Energy Ohio, Inc.

•

Duke Energy Indiana, Inc.

•

1. ORGANIZATION AND BASIS OF PRESENTATION

NATURE OF OPERATIONS AND BASIS OF CONSOLIDATION

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

These Condensed 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 Condensed Consolidated Financial Statements also reflect the Duke Energy Registrants’ proportionate share of certain 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 provisions 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 regulated public utility ~~that provides service~~primarily engaged in the generation, transmission and distribution of electricity and the transportation and sale of natural gas 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 has agreed to sell Duke Energy Ohio's nonregulated Midwest generation business, which sells power into wholesale energy markets, to Dynegy Inc. (Dynegy). See Note 2 for additional information.

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.~~

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

BASIS OF PRESENTATION

These Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles (GAAP) in the U.S. for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all information and notes required by GAAP in the U.S. for annual financial statements. Because the interim Condensed Consolidated Financial Statements and Notes do not include all information and notes required by GAAP in the U.S. for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the Consolidated Financial Statements and Notes in the Duke Energy Registrants’ combined Annual Report on Form 10-K for the year ended December 31, 2013.

On August 21, 2014, Duke Energy Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a purchase and sale agreement (PSA) with a subsidiary of Dynegy whereby Dynegy will acquire Duke Energy Ohio’s nonregulated Midwest generation business (Disposal Group). The results of operations of the nonregulated Midwest generation business have been classified as Discontinued Operations on the Condensed Consolidated Statements of Operations for the current and prior periods presented. Duke Energy has elected to present cash flows of discontinued operations combined with cash flows of continuing operations. See Note 2 for additional information.

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

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

Certain prior year amounts have been reclassified to conform to the current year presentation.

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 Condensed Consolidated Balance Sheets as shown in the following table. This table excludes amounts included in assets held for sale (AHFS).


(in millions)	June 30, 2014		December 31, 2013		September 30, 2014		December 31, 2013
Duke Energy	$	884	$	937	$	798	$	937
Duke Energy Carolinas	326		323		285		323
Progress Energy	269		189		232		189
Duke Energy Progress	157		120		131		120
Duke Energy Florida	112		69		101		69
Duke Energy Ohio	—		55		—		55
Duke Energy Indiana	27		5		26		5

Additionally, Duke Energy Ohio and Duke Energy Indiana sell, on a revolving basis, nearly all of their retail 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 Condensed Consolidated Balance Sheets of Duke Energy Ohio and Duke Energy Indiana. See Note 1213 for further information. These receivables for unbilled revenues are shown in the table below.


(in millions)	June 30, 2014		December 31, 2013		September 30, 2014		December 31, 2013
Duke Energy Ohio	$	64	$	89	$	54	$	89
Duke Energy Indiana	102		144		94		144

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

AMOUNTS ATTRIBUTABLE TO CONTROLLING INTERESTS

~~Loss From Discontinued Operations, net of tax presented on the respective Condensed Consolidated Statements of Operations for~~The following table presents Net Income Attributable to Duke Energy Corporation for continuing operations and ~~Progress Energy is attributable only to controlling interests~~discontinued operations for ~~all periods presented. Other comprehensive income reported on~~ the ~~respective Condensed Consolidated Statements of Equity for Duke Energy~~three and ~~Progress Energy is attributable only to controlling interests for all periods presented.~~nine months ended September 30, 2014 and 2013.



	Three Months Ended September 30,
	2014					2013
(in millions)	Duke Energy			Progress Energy		Duke Energy		Progress Energy
Income from Continuing Operations	$	891		$	330	$	946	$	328
Income of Continuing Operations Attributable to Noncontrolling Interests	3			1		4		1
Income from Continuing Operations Attributable to Duke Energy Corporation	$	888		$	329	$	942	$	327
Income From Discontinued Operations, net of tax	$	378		$	—	$	62	$	14
Loss of Discontinued Operations attributable to Noncontrolling Interests, net of tax	(8		)	—		—		—
Discontinued Operations Attributable to Duke Energy Corporation, net of tax	$	386		$	—	$	62	$	14
Net income	$	1,269		$	330	$	1,008	$	342
Net (Loss) Income Attributable to Noncontrolling Interest	(5		)	1		4		1
Net Income Attributable to Duke Energy Corporation	$	1,274		$	329	$	1,004	$	341



	Nine Months Ended September 30,
	2014						2013
(in millions)	Duke Energy			Progress Energy			Duke Energy			Progress Energy
Income from Continuing Operations	$	2,367		$	741		$	1,902		$	469
(Loss) Income of Continuing Operations Attributable to Noncontrolling Interests	11			2			12			2
Income from Continuing Operations Attributable to Duke Energy Corporation	$	2,356		$	739		$	1,890		$	467
(Loss) Income From Discontinued Operations, net of tax	$	(578	)	$	(6	)	$	82		$	10
Income (Loss) of Discontinued Operations attributable to Noncontrolling Interests, net of tax	(8		)	—			(5		)	—
Discontinued Operations Attributable to Duke Energy Corporation, net of tax	$	(570	)	$	(6	)	$	87		$	10
Net income	$	1,789		$	735		$	1,984		$	479
Net Income Attributable to Noncontrolling Interest	3			2			7			2
Net Income Attributable to Duke Energy Corporation	$	1,786		$	733		$	1,977		$	477

ACCUMULATED OTHER COMPREHENSIVE INCOME

For the three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013, reclassifications out of accumulated other comprehensive income (AOCI) for the Duke Energy Registrants were not material. Changes in AOCI for the Duke Energy Registrants are presented in their respective Condensed Consolidated Statements of Equity.

3536

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 operating revenues in the Condensed Consolidated Statements of Operations were as follows.


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Duke Energy	$	151	$	142	$	318	$	291	$	101	$	168	$	416	$	457
Duke Energy Carolinas	43		37		89		78		4		46		93		124
Progress Energy	74		73		151		141		63		89		214		230
Duke Energy Progress	24		27		56		55		—		33		56		88
Duke Energy Florida	50		46		95		86		63		56		158		142
Duke Energy Ohio	25		24		59		55		24		24		80		77
Duke Energy Indiana	9		8		19		17		10		9		29		26

During the third quarter of 2014, the North Carolina gross receipts tax was terminated due to the North Carolina Tax Simplification and Rate Reduction Act. The North Carolina gross receipts tax is no longer imposed effective July 1, 2014.

NEW ACCOUNTING STANDARDS

The new accounting standards adopted in 2014 and 2013 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.

The following new Accounting Standards Updates (ASUs) have been issued, but have not yet been adopted by the Duke Energy Registrants, as of ~~June~~September 30, 2014.

ASC 205 — Reporting Discontinued Operations. In April 2014, the ~~FASB~~Financial Accounting Standards Board (FASB) issued revised accounting guidance for reporting discontinued operations. A discontinued operation would be either (i) a component of an entity or a group of components of an entity that represents a separate major line of business or major geographical area of operations that either has been disposed of or is part of a single coordinated plan to be classified as held for sale or (ii) a business that, on acquisition, meets the criteria to be classified as held for sale.

For the Duke Energy Registrants, this guidance is effective on a prospective basis for interim and annual periods beginning January 1, 2015. This guidance will also result in increased disclosures. In general, this guidance is likely to result in fewer disposals of assets qualifying as discontinued operations.

ASC 606 -— Revenue from Contracts with Customers. In May 2014, the FASB issued revised accounting guidance for revenue recognition from contracts with customers. The core principle of this guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services.

For the Duke Energy Registrants, this guidance is effective for interim and annual periods beginning January 1, 2017. Duke Energy is currently evaluating the potential impact of the adoption of this revised accounting guidance on its revenue recognition and is unable to estimate at this time the impact of adoption on its consolidated results of operations, cash flows, financial position or disclosures.

2. ACQUISITIONS AND DISPOSITIONS

Purchase of NCEMPA's Generation

On ~~July 25,~~September 5, 2014, Duke Energy Progress executed an agreement to purchase North Carolina Eastern Municipal Power Agency’s (NCEMPA) ownership interests in certain generating assets jointly owned with and operated by Duke Energy Progress. The agreement provides for the acquisition of a total of approximately 700 MWmegawatts (MW) at Brunswick Nuclear Station, Shearon Harris Nuclear Station (Harris), Mayo Steam Station and Roxboro Steam Station. The purchase price for the ownership interest and fuel and spare parts inventory is approximately $1.2 billion. Under the agreement, Duke Energy Progress and NCEMPA will enter into a 30-year wholesale power supply agreement to continue meeting the needs of NCEMPA’s customers. There are several conditions precedent including state and federal regulatory approvals and legislative action required prior to completing the transaction. On October 10, 2014, Duke Energy Progress filed with the FERC for approval to purchase NCEMPA's interests in the generation assets. The agreement requires the transaction to be completed by the end of 2016.

Midwest Generation Exit

On ~~February 17,~~August 21, 2014, Duke Energy ~~Ohio announced it had initiated~~Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a ~~process to exit its nonregulated Midwest generation business.~~wholly owned subsidiary of Duke Energy Ohio, ~~expects~~entered into a PSA with a subsidiary of Dynegy whereby Dynegy will acquire Duke Energy Ohio’s Disposal Group for approximately $2.8 billion in cash subject to ~~dispose~~adjustments at closing for changes in working capital and capital expenditures. The completion of the ~~nonregulated Midwest generation business~~transaction is conditioned on expiration or termination of any applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, approval by FERC, and the ~~end~~release of certain credit support obligations. Closing is expected to be completed in the fourth quarter of 2014 or the first quarter of 2015. Based on this expected sale date, Duke Energy Ohio triggered held-for-sale accounting treatment on March 31, 2014. Duke Energy and Duke Energy Ohio have classified the assets and associated liabilities of this business as held for sale in the Condensed Consolidated Balance Sheet at June 30, 2014.

3637

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy and Duke Energy Ohio each recorded pretax impairments on these assets of approximately $1,402 million and $1,438 million, respectively, for the six months ended June 30, 2014, which represents the excess of the carrying value over the estimated fair value of the business, less estimated costs to sell. These losses were included in Impairment charges in the Condensed Consolidated Statements of Operations and Comprehensive Income. The fair value of the disposal group was based on the income approach, which estimates fair value using discounted cash flows, and indicative bids received to date. The impairment will be updated, if necessary, based on changes in estimated fair value as additional information related to the potential transaction becomes available.

Duke Energy and Duke Energy Ohio ceased depreciating the fixed assets of the disposal group on March 31, 2014. Duke Energy and Duke Energy Ohio avoided depreciation expense of $42 million for the three and six months ended June 30, 2014.

The ~~nonregulated Midwest generation business is~~Disposal Group was included in the Commercial Power segment. The following table presents information related to the Duke Energy Ohio generation plants included in the ~~disposal group.~~Disposal Group.



Facility	Plant Type	Primary Fuel	Location	Total Average MW Capacity^(c)	Owned Average MW Capacity^(c)	Ownership Interest
Stuart^(a)(b)	Fossil Steam	Coal	OH	2,318	904	39	%
Zimmer^(a)	Fossil Steam	Coal	OH	1,338	622	46.5	%
Hanging Rock	Combined Cycle	Gas	OH	1,274	1,274	100	%
Miami Fort (Units 7 and 8)^(a)	Fossil Steam	Coal	OH	1,020	653	64	%
Conesville^(a)(b)	Fossil Steam	Coal	OH	780	312	40	%
Washington	Combined Cycle	Gas	OH	637	637	100	%
Fayette	Combined Cycle	Gas	PA	640	640	100	%
Killen^(a)(b)	Fossil Steam	Coal	OH	618	204	33	%
Lee	Combustion Turbine	Gas	IL	640	640	100	%
Dick's Creek	Combustion Turbine	Gas	OH	136	136	100	%
Miami Fort	Combustion Turbine	Oil	OH	68	68	100	%
Total Midwest Generation				9,469	6,090


(a)	Jointly owned with Ohio Power Company and/or The Dayton Power & Light Company.


(b)	Station is not operated by Duke Energy Ohio.


(c)	Average MW capacity is calculated as the average of winter capacity and summer capacity.

The ~~disposal group~~Disposal Group also includes a retail sales business owned by Duke Energy. In the second quarter of 2014, Duke Energy Ohio removed Ohio Valley Electric Corporation (OVEC) from the ~~disposal group~~Disposal Group as it no longer ~~intends~~intended to sell it with the ~~nonregulated Midwest generation business.~~Disposal Group. Duke Energy Ohio has requested cost-based recovery of its contractual entitlement in OVEC in its 2014 Electric Security Plan (ESP) application filed on May 29, 2014. See Note 4 for information related to the 2014 ESP.

Duke Energy Ohio had triggered held for sale accounting treatment on March 31, 2014. The assets and associated liabilities of the Disposal Group are classified as held for sale in Duke Energy's and Duke Energy Ohio's Condensed Consolidated Balance Sheet at September 30, 2014.

Beginning in the third quarter of 2014, the results of operations of the Disposal Group are required to be classified as discontinued operations for current and prior periods in the accompanying Condensed Consolidated Statements of Operations and Comprehensive Income. Certain costs that are not material have remained in continuing operations that may be eliminated as a result of the sale. Results of discontinued operations were as follows.

Duke Energy



	Three Months Ended September 30,					Nine Months Ended September 30,
(in millions)	2014			2013		2014			2013
Operating Revenues	$	620		$	491	$	1,233		$	1,369
Estimated gain (loss) on disposition	460			—		(847		)	—

Income (loss) before income taxes	$	623		$	82	$	(864	)	$	126
Income tax expense (benefit)	218			34		(321		)	43
Income (loss) from discontinued operations of the Disposal Group	405			48		(543		)	83
Other, net of tax^(a)	(27		)	14		(35		)	(1		)
Income (Loss) from Discontinued Operations, net of tax	$	378		$	62	$	(578	)	$	82


(a)	Other discontinued operations relates to prior sales of businesses and includes indemnifications provided for certain legal, tax and environmental matters, and foreign currency translation adjustments.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy Ohio



	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014			2013
Operating Revenues	$	536	$	389	$	853		$	1,054
Estimated gain (loss) on disposition	466		—		(878		)	—

Income (loss) before income taxes	$	647	$	65	$	(917	)	$	71
Income tax expense (benefit)	234		30		(320		)	32
Income (Loss) from Discontinued Operations, net of tax	$	413	$	35	$	(597	)	$	39

The Duke Energy and Duke Energy Ohio held for sale assets include net pretax impairments of approximately $847 million and $878 million, respectively, for the nine months ended September 30, 2014. During the first quarter of 2014 an impairment was recorded to write-down the carrying amount of the assets to the estimated fair value of the business, less estimated costs to sell. For the three months ended September 30, 2014, a reversal of the pretax impairments was recorded of approximately $460 million and $466 million for Duke Energy and Duke Energy Ohio, respectively, based on the expected selling price to Dynegy less cost to sell. These losses and gains were included in Income (Loss) from Discontinued Operations, net of tax in the Condensed Consolidated Statements of Operations and Comprehensive Income. The impairment will be updated, if necessary, based on the final execution of the purchase sale agreement and any changes in estimated fair value as additional information related to the potential transaction becomes available.

Commercial Power has a revolving credit agreement (RCA) that is used to support the operations of the nonregulated Midwest generation business. Interest expense associated with the RCA has been allocated to discontinued operations. No other interest expense related to corporate level debt has been allocated to discontinued operations.

The following table presents the carrying values of the major classes of Assets held for sale and Liabilities associated with assets held for sale included in the ~~Midwest generation disposal group~~Disposal Group in the Condensed Consolidated Balance Sheets. Amounts included in the following table exclude certain other disposal groups which are not material and accordingly domay not agree to amounts presented in the Duke Energy Condensed Consolidated Balance Sheets.


	June 30, 2014				September 30, 2014
(in millions)	Duke Energy		Duke Energy Ohio		Duke Energy		Duke Energy Ohio
Current assets	$	409	$	359	$	335	$	284
Investments and other assets	42		37		43		38
Property, plant and equipment	2,153		2,116		2,675		2,644
Total assets held for sale	$	2,604	$	2,512	$	3,053	$	2,966
Current liabilities	$	271	$	257	$	284	$	269
Deferred credits and other liabilities	75		74		57		57
Total liabilities associated with assets held for sale	$	346	$	331	$	341	$	326

Duke Energy Ohio will continue to have transactions with the Disposal Group after the divestiture is complete. Duke Energy Ohio has a power purchase agreement with the Disposal Group, which extends through May 2015, for a portion of its standard service offer (SSO) supply requirement. In addition, for a period of up to 12 months, Duke Energy may provide transition services to Dynegy. Duke Energy will be reimbursed for transition services provided. The continuing cash flows are not expected to be material and are not considered direct cash flows. These arrangements do not allow Duke Energy or Duke Energy Ohio to significantly influence the operations of the Disposal Group once the sale is complete.

See Notes 4 and 5 for a discussion of contingencies related to the Disposal Group that will be retained by Duke Energy Ohio subsequent to the sale.

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 Condensed Consolidated Financial Statements. Certain governance costs are allocated to each segment. In addition, direct interest expense and income taxes are included in segment income.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Regulated Utilities conducts operations primarily through Duke Energy Carolinas, 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,~~builds, develops and operates renewable generation and ~~manages power plants and engages~~energy transmission projects throughout the continental U.S. As discussed in Note 2, Duke Energy entered into an agreement to sell Commercial Power's nonregulated Midwest generation business to Dynegy in a transaction that is expected to close in the ~~wholesale marketing and procurement~~fourth quarter of ~~electric power, fuel and emission allowances related to these plants as well as other contractual positions. Commercial Power’s generation~~2014 or the first quarter of 2015. As a result of this divestiture, the results of 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.~~nonregulated Midwest generation business have been reclassified to Discontinued Operations on the Condensed Consolidated Statements of Operations. Certain costs such as interest and ~~wind~~general and ~~solar generation located throughout~~administrative expenses previously allocated to 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.Disposal Group were not reclassified to discontinued operations.

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.


	Three Months Ended June 30, 2014																		Three Months Ended September 30, 2014
(in millions)	Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated			Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	5,272	$	364	$	304		$	5,940	$	9		$	—		$	5,949		$	5,975	$	366	$	50		$	6,391	$	4		$	—		$	6,395
Intersegment revenues	11		—		5			16		19			(35		)	—			11		—		—			11		21			(32		)	—
Total revenues	$	5,283	$	364	$	309		$	5,956	$	28		$	(35	)	$	5,949		$	5,986	$	366	$	50		$	6,402	$	25		$	(32	)	$	6,395
Segment income (loss)^(b)(a)	$	689	$	146	$	(120	)	$	715	$	(103	)	$	—		$	612		$	920	$	80	$	(17	)	$	983	$	(92	)	$	(3	)	$	888
Add back noncontrolling interests component																4																		3
Loss from discontinued operations, net of tax																(3		)
Income from discontinued operations, net of tax																																		378
Net income																$	613																	$	1,269
Segment assets	$	101,070	$	5,463	$	5,652		$	112,185	$	2,807		$	181		$	115,173		$	105,172	$	5,159	$	6,196		$	116,527	$	2,944		$	185		$	119,656

(a) Other includes costs to achieve the Progress Energy merger.



	Three Months Ended September 30, 2013
(in millions)	Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated
Unaffiliated revenues^(a)	$	5,768	$	370	$	56		$	6,194	$	23		$	—		$	6,217
Intersegment revenues	18		—		2			20		24			(44		)	—
Total revenues	$	5,786	$	370	$	58		$	6,214	$	47		$	(44	)	$	6,217
Segment income (loss)^(a)(b)	$	923	$	116	$	(28	)	$	1,011	$	(64	)	$	(5	)	$	942
Add back noncontrolling interests component																4
Income from discontinued operations, net of tax																62
Net income																$	1,008


(a)	~~Commercial Power includes a mark-to-market loss of $136 million, net of a tax benefit of $77 million, on economic hedges of~~In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the ~~input~~NCUC and ~~output commodities related to its fossil generation assets.~~the PSCSC. These rate increases impact Regulated Utilities.


(b)	Other includes costs to achieve the Progress Energy merger.

3840

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)


	Three Months Ended June 30, 2013																	Nine Months Ended September 30, 2014
(in millions)	Regulated Utilities		International Energy		Commercial Power		Total Reportable Segments		Other			Eliminations			Consolidated			Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated
Unaffiliated revenues^(b)	$	4,911	$	406	$	547	$	5,864	$	15		$	—		$	5,879		$	17,041	$	1,111	$	195		$	18,347	$	19		$	—		$	18,366
Intersegment revenues	9		—		10		19		21			(40		)	—			33		—		—			33		60			(93		)	—
Total revenues	$	4,920	$	406	$	557	$	5,883	$	36		$	(40	)	$	5,879		$	17,074	$	1,111	$	195		$	18,380	$	79		$	(93	)	$	18,366
Segment income (loss)^(e)(b)	$	353	$	87	$	41	$	481	$	(139	)	$	—		$	342		$	2,346	$	356	$	(70	)	$	2,632	$	(269	)	$	(7	)	$	2,356
Add back noncontrolling interests component															3																		11
Loss from discontinued operations, net of tax															(3		)																(578		)
Net income															$	342																	$	1,789


(a)	Commercial Power recorded a pretax impairment charge of $94 million related to reducing the carrying value of OVEC to zero. See Note 13 for additional information.


(b)	Other includes costs to achieve the Progress Energy merger.



	Nine Months Ended September 30, 2013
(in millions)	Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated
Unaffiliated revenues^(a)(b)(c)(d)	$	15,731	$	1,168	$	184		$	17,083	$	49		$	—		$	17,132
Intersegment revenues	35		—		5			40		64			(104		)	—
Total revenues	$	15,766	$	1,168	$	189		$	17,123	$	113		$	(104	)	$	17,132
Segment income (loss)^{(a)(b)(c)(d)(e)(f)}	$	1,932	$	300	$	(54	)	$	2,178	$	(278	)	$	(10	)	$	1,890
Add back noncontrolling interest																12
Income from discontinued operations, net of tax																82
Net income																$	1,984


(a)	In May 2013, the PUCO approved a Duke Energy Ohio settlement agreement that provides for a net annual increase in electric distribution revenues beginning in May 2013. This rate increase impacts Regulated Utilities.


(b)	In ~~May~~June 2013, ~~the~~ NCUC approved a Duke Energy Progress settlement agreement that included an increase in rates in the first year beginning in June 2013. This rate increase impacts Regulated Utilities.


(c)	In September 2013, Duke Energy Carolinas implemented revised customer rates approved by the NCUC and the PSCSC. These rate increases impact Regulated Utilities.


(d)	Regulated Utilities recorded an impairment charge related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information.

~~(d)~~(e)

Regulated Utilities recorded an impairment charge related to the letter Duke Energy Progress filed with the NRC requesting the NRC to suspend its review activities associated with the combined construction and operating license (COL) at ~~the Shearon~~ Harris ~~Nuclear Station (Harris)~~ site. Regulated Utilities also recorded an impairment charge related to the write-off of the wholesale portion of the Levy investments at Duke Energy Florida in accordance with the 2013 Settlement. See Note 4 for additional information.


~~(e)~~	~~Other includes costs to achieve the Progress Energy merger.~~

Six Months Ended June 30, 2014
(in millions) Regulated Utilities

International
Energy

Commercial
Power

Total
Reportable
Segments

Other
Eliminations
Consolidated
Unaffiliated revenues $ 11,067
$ 746
$ 746
$ 12,559
$ 14
$ —
$ 12,573
Intersegment revenues 21
—
12
33
39
(72 ) —
Total revenues $ 11,088
$ 746
$ 758
$ 12,592
$ 53
$ (72 ) $ 12,573
Segment income (loss)^(a)(b)(c)
$ 1,426
$ 276
$ (999 ) $ 703
$ (185 ) $ —
$ 518
Add back noncontrolling interests component 8
Loss from discontinued operations, net of tax (6 )
Net income $ 520


~~(a)~~	~~Commercial Power includes an impairment charge related to the planned disposition of the Midwest Generation assets. See Note 2 for additional information.~~


~~(b)~~	~~Commercial Power includes a mark-to-market loss of $158 million, net of a tax benefit of $89 million, on economic hedges of the input and output commodities related to its fossil generation assets.~~


~~(c)~~	~~Other includes costs to achieve the Progress Energy merger.~~

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

Six Months Ended June 30, 2013
(in millions) Regulated Utilities

International
Energy

Commercial
Power

Total
Reportable
Segments

Other
Eliminations
Consolidated
Unaffiliated revenues^(a)(b)
$ 9,963
$ 798
$ 986
$ 11,747
$ 30
$ —
$ 11,777
Intersegment revenues 17
—
23
40
41
(81 ) —
Total revenues $ 9,980
$ 798
$ 1,009
$ 11,787
$ 71
$ (81 ) $ 11,777
Segment income^{(a)(b)(c)(d)(e)}
$ 1,009
$ 184
$ (1 ) $ 1,192
$ (216 ) $ —
$ 976
Add back noncontrolling interest 3
Loss from discontinued operations, net of tax (3 )
Net income $ 976


~~(a)~~	In May 2013, the PUCO approved a Duke Energy Ohio settlement agreement that provides for a net annual increase in electric distribution revenues beginning in May 2013. This rate increase impacts Regulated Utilities.


~~(b)~~	~~In May 2013, the NCUC approved a Duke Energy Progress settlement agreement that included an increase in rates in the first year beginning in June 2013. This rate increase impacts Regulated Utilities.~~


~~(c)~~	~~Regulated Utilities recorded an impairment charge related to Duke Energy Florida's Crystal River Unit 3. See Note 4 for additional information.~~

~~(d)~~

Regulated Utilities recorded an impairment charge related to the letter Duke Energy Progress filed with the NRC requesting the NRC to suspend its review activities associated with the combined construction and operating license (COL) at the Shearon Harris Nuclear Station (Harris) site. Regulated Utilities also recorded an impairment charge related to the write-off of the wholesale portion of the Levy investments at Duke Energy Florida in accordance with the 2013 Settlement. See Note 4 for additional information.


~~(e)~~(f)	Other includes costs to achieve the Progress Energy merger.

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.

As discussed in Note 2, Duke Energy entered into an agreement to sell Commercial Power's nonregulated Midwest generation business to Dynegy in a transaction that is expected to be completed in the fourth quarter of 2014 or the first quarter of 2015. As a result of this divestiture, the results of operations of the nonregulated Midwest generation business have been reclassified to Discontinued Operations on the Condensed Consolidated Statements of Operations and Comprehensive Income. Amounts remaining in Commercial Power ~~owns, operates and manages power plants and engages~~relate to assets not included in the ~~wholesale marketing~~Disposal Group. Certain costs such as interest and ~~procurement of electric power, fuel~~general and ~~emission allowances related~~administrative expenses previously allocated to ~~these plants, as well as other contractual positions.~~

~~The remainder of Duke Energy Ohio’s operations is presented as Other. While it is~~the Disposal Group were not considered an operating segment, Other primarily includes certain governance costs allocated by its parent, Duke Energy. See Note 8 for additional information. All of Duke Energy Ohio’s revenues are generated domestically and its long-lived assets are all in the U.S.

reclassified to discontinued operations.

Three Months Ended June 30, 2014
(in millions) Regulated Utilities
Commercial Power
Total Reportable Segments
Other
Eliminations
Consolidated
Unaffiliated revenues^(a)
$ 415
$ 116
$ 531
$ —
$ —
$ 531
Intersegment revenues —
5
5
—
(5 ) —
Total revenues $ 415
$ 121
$ 536
$ —
$ (5 ) $ 531
Segment income (loss) / Consolidated net income^(a)(b)
$ 52
$ (154 ) $ (102 ) $ (5 ) $ —
$ (107 )
Segment assets $ 7,203
$ 2,818
$ 10,021
$ 103
$ (555 ) $ 9,569


~~(a)~~	~~In May 2013, the PUCO approved a settlement agreement that provides for a net annual increase in electric distribution revenues beginning in May 2013. This increase impacts Regulated Utilities.~~


~~(b)~~	Commercial Power includes an after-tax mark-to-market loss of $148 million, net of a tax benefit of $84 million, on economic hedges of the input and output commodities related to its fossil generation assets.

4041

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 9 for additional information. All of Duke Energy Ohio’s revenues are generated domestically and its long-lived assets are all in the U.S.


	Three Months Ended June 30, 2013														Three Months Ended September 30, 2014
(in millions)	Regulated Utilities		Commercial Power		Total Reportable Segments		Other			Eliminations			Consolidated		Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated
Unaffiliated revenues^(a)	$	404	$	407	$	811	$	—		$	—		$	811	$	440	$	6		$	446	$	—		$	—		$	446
Intersegment revenues	—		8		8		—			(8		)	—		1		—			1		—			(1		)	—
Total revenues	$	404	$	415	$	819	$	—		$	(8	)	$	811	$	441	$	6		$	447	$	—		$	(1	)	$	446
Segment income / Consolidated net income^(a)	$	27	$	35	$	62	$	(4	)	$	—		$	58
Segment income (loss)															$	43	$	(13	)	$	30	$	(4	)	$	—		$	26
Income from discontinued operations, net of tax																												$	413
Net income																												439
Segment assets															$	7,297	$	3,266		$	10,563	$	131		$	(622	)	$	10,072



	Three Months Ended September 30, 2013
(in millions)	Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations		Consolidated
Unaffiliated revenues	$	421	$	17		$	438	$	—		$	—	$	438
Total revenues	$	421	$	17		$	438	$	—		$	—	$	438
Segment income (loss)	$	42	$	(13	)	$	29	$	(5	)	$	—	$	24
Income from discontinued operations, net of tax													35
Net income													$	59



	Nine Months Ended September 30, 2014
(in millions)	Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations			Consolidated
Unaffiliated revenues	$	1,416	$	17		$	1,433	$	—		$	—		$	1,433
Intersegment revenues	1		—			1		—			(1		)	—
Total revenues	$	1,417	$	17		$	1,434	$	—		$	(1	)	$	1,433
Segment income (loss)^(a)	$	151	$	(101	)	$	50	$	(11	)	$	—		$	39
Loss from discontinued operations, net of tax														(597		)
Net loss														$	(558	)


~~(a)~~a)	~~In May 2013,~~Duke Energy Ohio recorded a pretax impairment charge of $94 million related to reducing the ~~PUCO approved a settlement agreement that provides~~carrying value of OVEC to zero. See Note 13 for ~~a net annual increase in electric distribution revenues beginning in May 2013. This increase impacts Regulated Utilities.~~additional information.


	Six Months Ended June 30, 2014																	Nine Months Ended September 30, 2013
(in millions)	Regulated Utilities		Commercial Power			Total Reportable Segments			Other			Eliminations			Consolidated			Regulated Utilities		Commercial Power			Total Reportable Segments		Other			Eliminations		Consolidated
Unaffiliated revenues^(a)	$	977	$	317		$	1,294		$	—		$	—		$	1,294		$	1,317	$	32		$	1,349	$	—		$	—	$	1,349
Intersegment revenues	—		12			12			—			(12		)	—
Total revenues	$	977	$	329		$	1,306		$	—		$	(12	)	$	1,294		$	1,317	$	32		$	1,349	$	—		$	—	$	1,349
Segment income (loss) / Consolidated net loss^(a)(b)(c)	$	116	$	(1,105	)	$	(989	)	$	(8	)	$	—		$	(997	)
Segment income (loss)																		$	122	$	(51	)	$	71	$	(14	)	$	—	$	57
Income from discontinued operations, net of tax																														39
Net income																														$	96


~~(a)~~	~~In May 2013, the PUCO approved a settlement agreement that provides for a net annual increase in electric distribution revenues beginning in May 2013. This increase impacts Regulated Utilities.~~


~~(b)~~	~~Commercial Power includes an impairment charge related to the planned disposition of the Midwest Generation assets. See Note 2 for additional information.~~


~~(c)~~	Commercial Power includes an after-tax mark-to-market loss of $181 million, net of a tax benefit of $101 million, on economic hedges of the input and output commodities related to its fossil generation assets.

Six Months Ended June 30, 2013
(in millions) Regulated Utilities
Commercial Power
Total Reportable Segments
Other
Eliminations
Consolidated
Unaffiliated revenues^(a)
$ 896
$ 662
$ 1,558
$ —
$ —
$ 1,558
Intersegment revenues —
19
19
—
(19 ) —
Total revenues $ 896
$ 681
$ 1,577
$ —
$ (19 ) $ 1,558
Segment income (loss) / Consolidated net income^(a)
$ 80
$ (33 ) $ 47
$ (10 ) $ —
$ 37

PART I


~~(a)~~	~~In May 2013, the PUCO approved a settlement agreement that provides for a net annual increase in electric distribution revenues beginning in May 2013. This increase impacts Regulated Utilities.~~

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY CAROLINAS, PROGRESS ENERGY, DUKE ENERGY PROGRESS, DUKE ENERGY FLORIDA AND DUKE ENERGY INDIANA

The remaining Subsidiary Registrants 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 ~~$60~~$58 million and ~~$70~~$64 million for the three months ended ~~June~~September 30, 2014 and 2013, respectively and ~~of $123~~$181 million and ~~$171~~$235 million for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013, respectively. The following table summarizes the net loss for Other at each of these registrants.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014			2013			2014			2013
Duke Energy Carolinas	$	(27	)	$	(25	)	$	(48	)	$	(43	)	$	(19	)	$	(26	)	$	(67	)	$	(69	)
Progress Energy	(45		)	(55		)	(97		)	(133		)	(48		)	(72		)	(145		)	(205		)
Duke Energy Progress	(3		)	(14		)	(13		)	(20		)	(10		)	(20		)	(23		)	(40		)
Duke Energy Florida	(7		)	(7		)	(11		)	(12		)	(5		)	(6		)	(16		)	(18		)
Duke Energy Indiana	(4		)	(4		)	(7		)	(8		)	(3		)	(5		)	(10		)	(13		)

The respective Regulated Utility operating segments include substantially all of Duke Energy Carolinas’, Progress Energy’s, Duke Energy Progress’, Duke Energy Florida’s and Duke Energy Indiana’s assets at ~~June~~September 30, 2014.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

4. REGULATORY MATTERS

RATE RELATED INFORMATION

The NCUC, PSCSC, FPSC, IURC, PUCO and KPSC approve rates for retail electric and natural gas services within their states. 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 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. 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. The North Carolina Supreme Court (NCSC) denied a motion to consolidate these appeals with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress on March 13, 2014. Briefing has concluded in this matter and oral argument ~~has been scheduled for~~occurred on September 8, 2014. Duke Energy Carolinas cannot predict the outcome of this matter.

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 NCUC Public Staff (Public Staff) was a party to the settlement. On October 23, 2013, the NCUC reaffirmed the rate of return approved in the settlement agreement, in response to an appeal by the NCAG. On November 21, 2013, the NCAG appealed the reaffirmed order. The NCSC denied a motion to consolidate this appeal with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress on March 13, 2014. Briefing has concluded in this matter and oral argument ~~has been scheduled for~~occurred on September 8, 2014. Duke Energy Carolinas cannot predict the outcome of this matter.

William States Lee Combined Cycle Facility

On April 9, 2014, the PSCSC granted Duke Energy Carolinas and North Carolina Electric Membership Corporation (NCEMC) a Certificate of Environmental Compatibility and Public Convenience and Necessity (CECPCN) for the construction and operation of a 750 MW combined cycle natural gas-fired generating plant at its existing William States Lee Generating Station in Anderson, South Carolina. On May 16, 2014, Duke Energy Carolinas announced its intention to begin construction in summer 2015 and estimates a cost to build of $600 million for its share of the facility, including ~~AFUDC.~~allowance for funds used during construction (AFUDC). The project is expected to be commercially available in late 2017. NCEMC will own approximately 13 percent of the project. On July 3, 2014, the South Carolina Coastal Conservation League (SCCCL) and Southern Alliance for Clean Energy (SACE) jointly filed a Notice of Appeal with the Court of Appeals of South Carolina seeking the court's review of the PSCSC's decision. Duke Energy Carolinas cannot predict the outcome of this matter.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 initial rate increase went into effect on June 1, 2013 and the step-in rate increase went into effect in June 2014.

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. The NCSC denied a motion to consolidate these appeals with other North Carolina rate case appeals involving Duke Energy Carolinas and Duke Energy Progress on March 13, 2014. Briefing has concluded in this matter and oral argument was held on May 5, 2014. On August 20, 2014, the NCSC affirmed the NCUC's order approving Duke Energy ~~Progress cannot predict the outcome~~Progress' rate of ~~this matter.~~return and capital structure.

Shearon Harris Nuclear Station Expansion

In 2006, Duke Energy Progress selected a site at Harris to evaluate for possible future nuclear expansion. On February 19, 2008, Duke Energy Progress filed its COL application with the NRC for two Westinghouse ~~Electric~~ AP1000 reactors at Harris, which the NRC docketed for review. On May 2, 2013, Duke Energy Progress filed a letter with the NRC requesting the NRC to suspend its review activities associated with the COL at the Harris site. As a result of the decision to suspend the COL applications, during the second quarter of 2013, Duke Energy Progress recorded a pretax impairment charge of $22 million, which represented costs associated with the COL, which were not probable of recovery. As of ~~June~~September 30, 2014, approximately $48 million is recorded in Regulatory assets on Duke Energy Progress' Condensed Consolidated Balance Sheet.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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 2013 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. Settlement was reached in October 2014, subject to FERC approval, for changes to the depreciation rates and conforming changes to the wholesale formula rates. The ~~parties are engaged in settlement discussions.~~agreement will have no material or adverse impact to the rates originally proposed by Duke Energy Progress, ~~cannot predict~~and Duke Energy Progress will receive cost recovery for early retired plants previously included in the ~~outcome of this matter.~~depreciation rates.

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. 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 issues related to (i) 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 and the 2013 Annual Report on Form 10-K for further discussion of these settlement agreements.

Crystal River Unit 3

On February 5, 2013, Duke Energy Florida announced the retirement of Crystal River Unit 3. 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, and March 2014, Duke Energy Florida filed an updated site-specific decommissioning plan with the NRC and FPSC, respectively. The plan included 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 to be completed by 2073. This decommissioning approach is currently utilized at a number of retired domestic nuclear power plants and is one of three accepted approaches to decommissioning approved by the NRC.

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. Duke Energy agreed to ~~forego~~forgo recovery of $295 million of regulatory assets and an impairment charge was recorded in the second quarter of 2013 for this matter. 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 an Independent Spent Fuel Storage Installation (ISFSI). 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. In May 2014, Duke Energy Florida petitioned the FPSC for approval of the decision to construct the ISFSI and approval of an accounting order to defer amortization of the ISFSI ~~construction~~ pending resolution of its litigation against the federal government as a result of the Department of Energy's breach of its obligation to ~~remove the~~accept spent nuclear fuel. The regulatory asset associated with the original power uprate project to increase generating capacity ~~and replace two steam generators~~ will continue to be recovered through the Nuclear Cost Recovery Clause (NCRC) over an estimated seven year period ~~beginning~~that began in 2013.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Through ~~June~~September 30, 2014, Duke Energy Florida deferred ~~$1,337~~$1,373 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 ~~$281~~$268 million for recovery associated with building an ISFSI 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 costs to exceed the cap.

The following table includes a summary of retail customer refunds agreed to in the 2012 Settlement and the 2013 Settlement. Refer to the 2013 Annual Report on Form 10-K for additional information on each of these refunds.


	June 30, 2014															September 30, 2014
							Remaining Amount to be Refunded															Remaining Amount to be Refunded
(in millions)	Total			Refunded to date			2014			2015			2016			Total			Refunded to date			2014			2015			2016
2012 Settlement refund	$	288		$	199		$	69		$	10		$	10		$	288		$	233		$	35		$	10		$	10
Retirement decision refund	100			—			—			40			60			100			—			—			40			60
NEIL proceeds	490			408			82			—			—			490			449			41			—			—
Total customer refunds	$	878		607			151			50			70			$	878		682			76			50			70
Accelerated regulatory asset recovery	(130		)	(17		)	(20		)	(37		)	(56		)	(130		)	(28		)	(9		)	(37		)	(56		)
Net customer refunds	$	748		$	590		$	131		$	13		$	14		$	748		$	654		$	67		$	13		$	14

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

Levy

On July 28, 2008, Duke Energy Florida applied to the NRC for a ~~Combined Construction and Operating License (COL)~~COL for two Westinghouse AP1000 reactors at Levy. 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.

On January 28, 2014, Duke Energy Florida terminated the Levy engineering, procurement and construction agreement (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 recorded an exit obligation of $25 million upon termination of the EPC. This liability was recorded within Other in Deferred Credits and Other Liabilities with an offset primarily to Regulatory assets on the Condensed Consolidated Balance Sheets. Duke Energy Florida is allowed to recover reasonable and prudent EPC cancellation costs from its retail customers. ~~See Note 5 for a discussion of litigation related to the EPC termination.~~

The 2012 Settlement provided that Duke Energy Florida include 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. In accordance with the 2013 Settlement, Duke Energy Florida ceased amortization of the wholesale allocation of Levy investments against retail rates. In the second quarter of 2013, Duke Energy Florida recorded a pretax charge of $65 million to write off the wholesale portion of Levy investments. This amount is included in Impairment charges on Duke Energy Florida's Condensed Statements of Operations and Comprehensive Income.

On October 27, 2014, the FPSC approved Duke Energy Florida rates for 2015 for Levy as filed and consistent with those established in the 2013 Revised and Restated Settlement Agreement. 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 ~~June~~September 30, 2014, Duke Energy Florida has a net uncollected investment in Levy of approximately ~~$233~~$207 million, including AFUDC. Of this amount, ~~$18~~$54 million is included in Regulatory assets, $120 million related to land and the COL is included in Net, property, plant and equipment, and ~~$95~~$33 million is included in Regulatory assets within Current Assets on the Condensed Consolidated Balance Sheets.

New Generation

The 2013 Settlement establishes a recovery mechanism for additional generation needs. This recovery mechanism, the Generation Base Rate Adjustment (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 May 27, 2014, Duke Energy Florida petitioned the FPSC for a Determination of Need to (i) construct a 1,640 MW combined cycle natural gas plant in Citrus County, Florida to be in service in 2018 with an estimated cost of $1.5 billion, (ii) construct a 320 MW combustion turbine plant at its existing Suwannee generating facility with an estimated cost of $197 million, and (iii) add inlet chilling to its existing Hines Energy Complex (Hines) combined cycle units which will increase the output of those units by 220 MW at an estimated cost of $160 million. These cost estimates include AFUDC. ~~Hearings~~On August 26, 2014, Duke Energy Florida requested the FPSC withdraw consideration for ~~these matters are scheduled~~the Suwannee project so that Duke Energy Florida could pursue further negotiations on an alternative power plant acquisition. On October 2, 2014, the FPSC approved the requests for ~~August~~the Citrus County plant and ~~September 2014.~~the uprate project at the Hines facility. Additional environmental and governmental approvals will be sought for the Citrus County project. The Hines uprate project is expected to be completed no later than 2017.

Cost of Removal Reserve

The 2012 Settlement and the 2013 Settlement provided 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 reaching zero or the expiration of the 2013 Settlement. Duke Energy Florida was not allowed to 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 ~~$17~~$22 million for the three months ended ~~June~~September 30, 2013 and ~~$73~~$95 million for the ~~six~~nine months ended ~~June~~September 30, 2013. Duke Energy Florida had no cost of removal reserves eligible for amortization to income remaining after December 31, 2013.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy Ohio

Ohio River Fuel Spill

On August 18, 2014, approximately 9,000 gallons of fuel oil was inadvertently discharged into the Ohio River during a fuel oil transfer at the W.C. Beckjord generating plant. The total costs to be incurred related to the clean-up of the oil spill are not expected to be material.

2014 Electric Security Plan

On May 29, 2014, Duke Energy Ohio filed an application for approval of ~~a standard service offer (SSO)~~an SSO in the form of an ~~electric security plan (ESP),~~ESP, effective June 1, 2015. The proposed ESP includes a competitive procurement process for SSO load, a distribution capital investment rider, a tracking mechanism for incremental distribution costs caused by major storms, and a cost-based recovery of Duke Energy Ohio’s contractual entitlement in OVEC. The proposed plan also seeks rate design modifications and continuance, revision, or termination of existing riders. ~~The~~An evidentiary hearing for this case ~~is scheduled for hearing beginning~~commenced on ~~September 8, 2014, although various intervenors have sought an approximate two-month delay in the hearing date.~~October 22, 2014. Duke Energy Ohio cannot predict the outcome of this matter.

2012 Natural Gas Rate Case

On November 13, 2013, the PUCO issued an order approving a settlement among Duke Energy Ohio, the PUCO Staff and intervening parties (the Gas Settlement). The Gas Settlement provided for (i) no increase in base rates for natural gas distribution service, (ii) a return on equity of 9.84 percent, and (iii) rider recovery of $56 million, excluding carrying costs, of environmental remediation costs associated with former manufactured gas plants (MGP) incurred through 2012. The MGP rider became effective in April 2014 for a five-year period. On March 31, 2014, Duke Energy Ohio filed an application with the PUCO to adjust the MGP rider for investigation and remediation costs incurred in 2013.

On May 14, 2014, the Ohio Supreme Court granted certain consumer groups' motion to stay the MGP rider pending their appeals of the PUCO approval of the Gas Settlement. The appellants, the PUCO and Duke Energy Ohio have all filed briefs addressing the merits of this matter with the Ohio Supreme Court. On July 29, 2014, the Ohio Supreme Court denied Duke Energy Ohio's motion to lift the stay, but did require appellants to post a bond. ~~The court further directed parties to submit briefs, no later than August 13, 2014, to assist~~Briefs have been submitted in ~~setting an appropriate~~the case. No bond ~~amount. Billing~~amount or date for oral argument has been set. Duke Energy Ohio suspended billing of the MGP rider ~~was suspended~~ in June 2014. Amounts collected under the rider prior to suspension are immaterial. Duke Energy Ohio cannot predict the outcome of this matter.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

Regional Transmission Organization (RTO) Realignment

Duke Energy Ohio, including Duke Energy Kentucky, transferred control of its transmission assets from Midcontinent Independent System Operator, Inc. (MISO) to PJM Interconnection, LLC (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~~Planning (MTEP) costs, including but not limited to Multi-Value Project (MVP) costs, directly or indirectly charged to Ohio 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 Condensed 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. As of ~~June~~September 30, 2014, $74 million is recorded as a Regulatory asset on Duke Energy Ohio's Condensed Consolidated Balance Sheets.


(in millions)	December 31, 2013		Provision / Adjustments		Cash Reductions			June 30, 2014		December 31, 2013		Provision / Adjustments		Cash Reductions			September 30, 2014
Duke Energy Ohio	$	95	$	1	$	(2	)	$	94	$	95	$	3	$	(3	)	$	95

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 the 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,~~operations and maintenance, taxes and return over the project lives, the number of years in service for the projects and the allocation to Duke Energy Ohio.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Any liability related to the MISO MVP matter attributable to the Disposal Group will not be transferred to Dynegy upon closing of the disposal of the Midwest generation business.

Duke Energy Indiana

Edwardsport ~~IGCC~~Integrated Gasification Combined Cycle (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 618MW 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. The Citizens Action Coalition of Indiana, Inc., Sierra Club, Inc., Save the Valley, Inc., and Valley Watch, Inc. (collectively, the Joint Intervenors) were intervenors in several matters related to the Edwardsport IGCC Plant.

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. 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.

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. Updates to the IGCC rider are filed semi-annually. An order on the eleventh semi-annual IGCC rider is currently pending. The twelfth and thirteenth semi-annual IGGC riders have been combined and are scheduled for hearings in ~~November 2014.~~February 2015.

On March 18, 2014, the Indiana Court of Appeals denied an appeal filed by the Joint Intervenors and affirmed the IURC order approving the 2012 Edwardsport settlement and other related regulatory orders. On June 5, 2014, the Indiana Court of Appeals affirmed the decision on rehearing. The Joint Intervenors ~~have~~ requested to seek transfer to the Indiana Supreme Court.

~~PART I~~

~~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.~~

~~Combined Notes~~ On November 7, 2014, the Indiana Supreme Court denied the Joint Intervenors' request to ~~Condensed Consolidated Financial Statements – (Continued)~~transfer the appeal of these proceedings. The ninth and tenth semi-annual IGCC rider orders have also been appealed. On August 21, 2014, the Indiana Court of Appeals affirmed the IURC order in the tenth IGCC rider proceeding, and on October 29, 2014, denied Joint Intervenors' request for rehearing. On September 8, 2014, the Indiana Court of Appeals remanded the IURC order in the ninth IGCC rider proceeding back to the IURC for further findings concerning approximately $61 million of financing charges Joint Intervenors claimed were caused by construction delay and a ratemaking issue concerning the in-service date determination for tax purposes.

~~(Unaudited)~~

On April 2, 2014, the IURC established a subdocket to Duke Energy Indiana’s current fuel adjustment clause proceeding. In this fuel adjustment subdocket, the IURC intends to review underlying causes for net negative generation amounts at the Edwardsport IGCC plant during the period September through November 2013. Duke Energy Indiana contends the net negative generation is related to the consumption of fuel and auxiliary power when the plant was in start-up or off line. In addition to the OUCC, the Duke Energy Indiana Industrial Group, Nucor Steel-Indiana, Steel Dynamics, Inc., and the Joint Intervenors are parties to the subdocket. The IURC has deferred the fuel adjustment subdocket until resolution of the twelfth and thirteenth semi-annual IGCC rider proceedings. In addition, although the IURC approved fuel adjustment clause recovery for the period December 2013 through March 2014, it determined such fuel costs reasonably related to the operational performance of the Edwardsport IGCC plant shall be subject to refund pending the outcome of the twelfth and thirteenth semi-annual IGCC riders.

Duke Energy Indiana cannot predict the outcome of the fuel adjustment clause ~~subdocket~~proceedings or pending and future IGCC Rider proceedings.

Grid Infrastructure Improvement Plan

On August 29, 2014, Duke Energy Indiana filed a seven-year grid infrastructure improvement plan with the IURC with an estimated cost of $1.9 billion, focusing on the reliability, integrity and modernization of the transmission and distribution system. If approved, eighty percent of the costs will be recovered through a rate tracker. The remaining twenty percent are subject to recovery through future rate case proceedings. Hearings are set for December 2014 and Duke Energy Indiana expects a decision in the second quarter of 2015.

OTHER REGULATORY MATTERS

Atlantic Coast Pipeline

On September 2, 2014, Duke Energy, Dominion Resources (Dominion), Piedmont Natural Gas and AGL Resources announced the formation of a joint venture, Atlantic Coast Pipeline, LLC, to build and own the proposed Atlantic Coast Pipeline (ACP), a 550-mile interstate natural gas pipeline. The ACP is designed to meet the needs identified in requests for proposals by Duke Energy Carolinas, Duke Energy Progress and Piedmont Natural Gas. Dominion will build and operate the ACP and will own 45 percent. Duke Energy will have a 40 percent ownership of the pipeline through its Commercial Power segment. The remaining share will be owned by Piedmont Natural Gas and AGL Resources. Duke Energy Carolinas and Duke Energy Progress, among others, will be customers of the pipeline. Purchases will be made under several 20-year supply contracts, subject to state regulatory approval. In October 2014, the NCUC and PSCSC approved the Duke Energy Carolinas and Duke Energy Progress requests to enter into certain affiliate agreements, pay compensation to ACP and to grant a waiver of certain Code of Conduct provisions relating to contractual and jurisdictional matters. The project will require FERC approval, which the joint venture will seek to secure by summer 2016. The estimated in-service date of the pipeline is late 2018.

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.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

On November 6, 2013, the North Carolina Court of Appeals heard oral arguments on the appeals. On March 4, 2014, the Court of Appeals issued an opinion affirming the NCUC’s approval of the merger. On April 8, 2014, NC WARN filed a petition for discretionary review by the North Carolina Supreme Court. On April 21, 2014, Duke Energy and the ~~NCUC~~ Public Staff jointly filed their response opposing NC WARN’s petition. The City of Orangeburg did not file a petition for discretionary review. Duke Energy cannot predict the outcome of these matters.

Progress Energy Merger FERC Mitigation

In June 2012, the FERC approved the merger with Progress Energy, including Duke Energy and Progress Energy’s revised market power mitigation plan, the Joint Dispatch Agreement (JDA) and the joint Open Access Transmission Tariff. ~~On August 8, 2012, FERC granted certain intervenors’ request~~Several intervenors filed requests for rehearing challenging various aspects of the FERC approval. On October 29, 2014, FERC denied all of the requests for ~~further consideration.~~rehearing.

The revised market power mitigation plan provided for the acceleration of one transmission project and the completion of seven other transmission projects ~~(Long-term~~(Long-Term FERC Mitigation) and interim firm power sale agreements during the completion of the transmission projects (Interim FERC Mitigation). The ~~Long-term~~Long-Term FERC Mitigation was 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. All of these projects were completed in or before 2014. On May 30, 2014, the Independent Monitor filed with FERC a final report stating that the Long-Term FERC Mitigation is complete. Therefore, Duke Energy Carolinas' and Duke Energy Progress' obligations associated with the Interim FERC Mitigation have terminated. In the second quarter of 2014, Duke Energy Progress recorded an $18 million partial reversal of an impairment recorded in the third quarter of 2012. This reversal adjusts the initial disallowance from the ~~Long-term~~Long-Term FERC mitigation and reflects updated information on the construction costs and in-service dates of the transmission projects.

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 to the FERC disclosing the error and arguing that no additional mitigation is necessary. ~~On March 28, 2014, Duke Energy submitted responses to a FERC deficiency letter seeking additional information concerning the market power mitigation calculations.~~ The City of New Bern filed a protest ~~to Duke Energy’s response~~ and requested that FERC order additional mitigation. On October 29, 2014, FERC ordered that the amount of the stub mitigation be increased from 25 MW to 129 MW. The stub mitigation is Duke’s commitment to set aside for third parties a certain quantity of firm transmission capacity from Duke Energy ~~cannot predict~~Carolinas to Duke Energy Progress during summer off-peak hours. FERC also ordered that Duke Energy operate certain phase shifters to create additional import capability and that such operation be monitored by an independent monitor. Duke Energy does not expect the ~~outcome of~~costs to comply with this ~~matter.~~order to be material.

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 to 20-year period, and options being considered to meet those needs. Recent IRPs filed by the Subsidiary Registrants 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~~United States Environmental Protection Agency (EPA) regulations recently approved or ~~that are not yet effective.~~proposed.

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.


	June 30, 2014												September 30, 2014
	Duke Energy		Duke Energy Carolinas^(b)		Progress Energy		Duke Energy Florida^(c)		Duke Energy Ohio^(d)		Duke Energy Indiana^(e)		Duke Energy		Duke Energy Carolinas^(b)		Progress Energy		Duke Energy Florida^(c)		Duke Energy Ohio^(d)		Duke Energy Indiana^(e)
Capacity (in MW)	2,297		200		873		873		556		668		2,297		200		873		873		556		668
Remaining net book value (in millions)^(a)	$	253	$	13	$	111	$	111	$	9	$	120	$	256	$	19	$	109	$	109	$	9	$	119


(a)	Included in Property, plant and equipment, net as of ~~June~~September 30, 2014, on the Condensed 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 5 and 6 and Miami Fort Unit 6. Beckjord units have no remaining book ~~value.~~value and were retired October 1, 2014.


(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.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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.

5. COMMITMENTS AND CONTINGENCIES

ENVIRONMENTAL

Duke Energy is subject to international, federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal, and other environmental matters. The Subsidiary Registrants are subject to federal, state, and local regulations regarding air and water quality, hazardous and solid waste disposal and other environmental matters. These regulations can be changed from time to time, imposing new obligations on the Duke Energy Registrants.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 have 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 Condensed Consolidated Statements of Operations unless regulatory recovery of the costs is deemed probable.

The following table contains information regarding reserves for probable and estimable costs related to the various environmental sites. These reserves are recorded in Other within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheets.


	Six Months Ended June 30, 2014																				Nine Months Ended September 30, 2014
(in millions)	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
Balance at beginning of period	$	79		$	11		$	27		$	8		$	19		$	27		$	7	$	79		$	11		$	27		$	8		$	19		$	27		$	7
Provisions / adjustments	9			(1		)	4			3			1			5			—
Provisions/adjustments																					34			(1		)	4			3			1			28			3
Cash reductions	(6		)	—			(4		)	(2		)	(2		)	(1		)	—		(8		)	—			(6		)	(4		)	(2		)	(1		)	(1		)
Balance at end of period	$	82		$	10		$	27		$	9		$	18		$	31		$	7	$	105		$	10		$	25		$	7		$	18		$	54		$	9


	Six Months Ended June 30, 2013																				Nine Months Ended September 30, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana			Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Balance at beginning of period	$	75		$	12	$	33		$	14		$	19		$	15		$	8		$	75		$	12	$	33		$	14		$	19		$	15		$	8
Provisions / adjustments	4			—		4			1			3			(1		)	1
Provisions/adjustments																					6			—		5			1			4			(1		)	1
Cash reductions	(12		)	—		(3		)	(1		)	(2		)	(6		)	(2		)	(17		)	—		(6		)	(2		)	(4		)	(8		)	(2		)
Balance at end of period	$	67		$	12	$	34		$	14		$	20		$	8		$	7		$	64		$	12	$	32		$	13		$	19		$	6		$	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	$	90	$	83
Duke Energy Carolinas	25		25
Progress Energy	9		9
Duke Energy Progress	2		2
Duke Energy Florida	7		7
Duke Energy Ohio	51		42
Duke Energy Indiana	5		7

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

Ash Basins

On February 2, 2014, a break in a 48-inch 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 48-inch stormwater pipe, stopping the release of materials into the river. On February 21, 2014, a permanent plug was installed in a 36-inch stormwater pipe beneath ~~the~~an adjacent ash basin. 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 during the incident. Duke Energy Carolinas incurred approximately $20 million of repairs and remediation expense related to this incident during the ~~six~~nine months ended ~~June~~September 30, 2014. These amounts are recorded in Operations, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income. Duke Energy Carolinas will not seek recovery of these costs from ratepayers. In July, Duke Energy completed remediation work identified by the EPA. Other costs related to the Dan River release ~~and the overall ash management plan,~~ including future regulatory directives, natural resources damages, pending litigation, future claims or litigation, and long-term environmental impact costs ~~long-term operational changes, and costs associated with new laws and regulations,~~ cannot be reasonably estimated at this time. ~~However, the total costs~~

PART I

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.

Combined Notes to ~~be incurred for any potential additional remediation relating to the Dan River ash release are not expected to be material.~~Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy ~~has~~ engaged third-party engineering experts to complete an independent engineering review of all its ash basins. Initial field work has been completed. Findings and recommendations are being reviewed with management and repair actions are being taken to address the findings. Duke Energy is also preparing a comprehensive, longer-term ash basin strategy, which will involve a site by site analysis of applicable laws, regulations, site characteristics, and engineering feasibility. ~~We expect this work to be completed by the end of the year, with detailed engineering to follow.~~ Each site is unique, and site-specific engineering will help determine the most appropriate closure method for that site.

On ~~March 12,~~September 20, 2014, ~~Duke Energy issued a letter to the governor of the state of North Carolina and the secretary of~~ the North Carolina ~~Department~~Coal Ash Management Act of Environment and Natural Resources (DENR) outlining recommendations for near-term and longer-term action at its ash basins in North Carolina. Implementing the near-term recommendations and longer-term plans depends on receipt of various state and federal permits and determinations that these actions are prudent, cost-effective and environmentally sound.2014 (Coal Ash Act) became law. The near-term actions outlined in the letter include moving ash from basins at three coal plants to lined fill solutions, converting the remaining coal units to dry fly ash handling or retiring the units, and minimizing potential risk of an incident similar to Dan River by removing water from ash basins at all retired North Carolina coal plants.

On April 22, 2014, a representative of Duke Energy appeared before the Environmental Review Commission of the North Carolina General Assembly and outlined cost estimates for a range of ash handling and ash basin closure options. The table below summarizes estimated costs of various potential approaches to ash management for North Carolina ash basins. These amounts represent a rough order of magnitude and are not detailed engineering grade estimates. The estimates assume coal ash will retain a non-hazardous designation by the EPA and exclude financing costs. Any ultimate activities and resultant costs will be dependent upon state and federal environmental requirements.

(in billions) Range
Baseline assumptions^(a)
$ 2.0
- $ 2.5
Estimated additional costs related to full excavation^(b)
4.0
- 5.5
Estimated additional costs related to all-dry systems^(c)
1.0
- 2.0
Total range of costs^(d)
$ 2.0
- $ 10.0

~~(a)~~

Assumes (i) hybrid cap in place closure for ash basins at ten coal plants, (ii) excavation and relocation of ash to lined structural fills or landfills for the retired Dan River, Riverbend and Sutton coal plants, (iii) dry fly ash conversion at the Asheville units and Cliffside Unit 5, (iv) continued structural fill disposal for the Asheville coal plant, and (v) dry bottom ash handling conversions and fly ash reliability improvements. Includes costs for actions noted in the March 12, 2014 letter to the governor of North Carolina and existing plans to close ash basins.


~~(b)~~	~~Represents estimated additional costs to excavate and relocate ash to lined landfills for the ten plants under hybrid cap in place closure in the baseline assumptions.~~


~~(c)~~	~~Represents estimated additional costs to convert all active coal plants to all-dry pneumatic bottom ash handling systems and thermally-driven evaporation of other process water.~~


~~(d)~~	On average, the allocation of these estimates is approximately 65 percent to Duke Energy Carolinas and 35 percent to Duke Energy Progress. However, this allocation could vary significantly based on site-specific compliance actions.

~~The North Carolina Senate adopted a~~ bill ~~on June 25, 2014, which would~~ (i) ~~establish~~establishes a Coal Ash Management Commission to oversee handling of coal ash within the state; (ii) ~~prohibit~~prohibits construction of new and expansion of existing ash ~~impoundments;~~impoundments and use of existing impoundments at retired facilities, effective October 1, 2014; (iii) ~~require~~requires closure of ash impoundments at Duke Energy Progress' Asheville and Sutton stations and Duke Energy Carolinas' Riverbend and Dan River ~~and Sutton~~ stations no later than August 1, 2019; (iv) ~~require an evaluation and ranking~~requires conversion to dry fly ash handling at active plants not retired by December 31, 2018; (v) requires conversion to dry bottom ash handling at active plants by December 31, 2019, or retirement of active plants; (vi) requires all remaining ash impoundments in North Carolina ~~with closure of all basins within~~to be approved as high-risk, intermediate-risk, or low-risk no later than ~~fifteen years, (v) establish~~December 31, 2015 by The North Carolina Department of Environment and Natural Resources (DENR) with the method of closure and timing to be based upon the assigned risk, with closure no later than December 31, 2029; (vii) establishes requirements to deal with groundwater and surface water impacts from impoundments and ~~(vi) enhance~~(viii) enhances the level of regulation for structural fills utilizing coal ash. ~~On July 3, 2014, the North Carolina House adopted its version of the bill with several differences including a~~A variance procedure for compliance deadlines and modification of requirements regarding structural fills and compliance ~~boundaries. Both proposed laws, as written, leave~~boundaries is also outlined. Provisions of the bill prohibit cost recovery for unlawful discharge of ash basin waters occurring after January 1, 2014. The Coal Ash Act includes a moratorium for any NCUC ordered rate changes to effectuate the legislation, which ends January 15, 2015. The Coal Ash Act leaves the decision on cost recovery determinations related to closure of coal combustion residuals surface impoundments (ash basins or impoundments) to the ~~state utilities commissions after~~normal ratemaking processes before utility regulatory commissions. In September 2014, Duke Energy Carolinas executed a ~~moratorium ending no later than December 31, 2016. However,~~consent agreement with the ~~proposed laws do not prohibit requests for regulatory deferral orders during~~South Carolina Department of Health and Environmental Control (SCDHEC) requiring the ~~moratorium. The legislature appointed a conference committee to resolve differences in~~retirement of an inactive ash basin at the two bills. However, the North Carolina General Assembly did not pass final legislation prior to adjourning its session in early August 2014. Coal ash legislation could be considered during a reconvened legislative session later in 2014.W.S. Lee Steam Station.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

Duke Energy ~~records~~Carolinas and Duke Energy Progress recorded asset retirement obligations ~~when it has a~~at September 30, 2014 based upon the legal obligation ~~to incur retirement costs associated with the retirement~~for closure of ~~a long-lived asset~~coal ash basins and the ~~obligation can be reasonably estimated. Duke Energy has not recorded an~~disposal of related ash as a result of the Coal Ash Act and the agreement with SCDHEC. Refer to Note 7 for further discussion of the asset retirement obligation related to these proposals as a legal obligation has not yet been incurred. As the necessary approvals are obtained to permit the work to proceed an asset retirement obligation could be recorded. Cost recovery for these expenditures will be pursued through the normal ratemaking process with state utility commissions, which permits the recovery of necessary and prudently incurred costs associated with Duke Energy's regulated operations. While Duke Energy cannot predict the outcome of these matters, it believes compliance costs will be within the range outlined in the above table. However, ultimate costs will be largely dependent upon compliance alternatives allowed to meet requirements of the legislation, once enacted.obligations recorded at September 30, 2014.

LITIGATION

Duke Energy

Ash Basin Shareholder Derivative Litigation

~~Two~~Five shareholder derivative lawsuits have been filed relating to the release at Dan River and to the management of Duke Energy’s ash basins. The ~~first lawsuit was~~lawsuits were filed ~~on May 21, 2014,~~ in Delaware Chancery Court on (i) May 21, 2014, by shareholders Edward Tansey and the Police Retirement System of St. ~~Louis~~Louis; (ii) July 18, 2014, by shareholder Robert Reese; (iii) August 5, 2014, by shareholder Leatrice Seinfeld; (iv) September 2, 2014, by the City of Birmingham; and ~~names~~(v) October 3, 2014, by shareholder Andrew Behar.

The lawsuits name as defendants several current and former Duke Energy officers and directors ~~together with all current directors of Duke Energy~~ (collectively, the “Duke Energy Defendants”). ~~The second lawsuit was filed against the Duke Energy Defendants on July 18, 2014, in Delaware Chancery Court by shareholder Robert Reese.~~ Duke Energy is named as a nominal defendant in ~~both~~all five lawsuits.

~~Both~~All of the complaints allege the Duke Energy Defendants breached their fiduciary duties to the company by failing to adequately oversee Duke Energy’s ash basins since 2008 and that these breaches of fiduciary duty may have contributed to the incident at Dan River and continued thereafter. The ~~Tansey complaint~~lawsuits also ~~asserts~~assert claims against the Duke Energy Defendants for corporate waste (relating to the money Duke Energy has spent and will spend as a result of the fines, penalties, and coal ash removal) and unjust enrichment (relating to the compensation and director remuneration that was received despite these alleged breaches of fiduciary duty). The lawsuits seek both injunctive relief against Duke Energy and restitution from the Duke Energy Defendants.

On May 28, 2014, Duke Energy received a shareholder litigation demand letter sent on behalf of shareholder Mitchell Pinsly. The letter alleges that the members of the Duke Energy Board of Directors and certain officers breached their fiduciary duties by allowing the company to illegally dispose of and store coal ash pollutants. The letter demands that the Board of Directors take action to recover damages associated with those breaches of fiduciary duty; otherwise, the attorney will file a shareholder derivative action. By letter dated July 3, 2014, counsel for the shareholder was informed that the Board of Directors appointed a Demand Review Committee to evaluate the allegations in the Demand Letter.

On October 31, 2014, the Delaware Chancery Court judge issued an order consolidating the five lawsuits. 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

Duke Energy, the 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) and certain Duke Energy officers are 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.~~Chief Executive Officer (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. ~~An attempt~~On August 15, 2014, the parties reached an agreement in principle to settle the litigation for an amount which, net of the expected proceeds of insurance policies, is not anticipated to have a material effect on ~~May 14, 2014,~~the results of operations, cash flows or financial position of Duke Energy. The agreement in principle is subject to ~~mediate~~ the ~~claims was unsuccessful.~~execution of a term sheet, which is being negotiated, and will be submitted to the court for approval.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 the Legacy Duke 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.

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 the 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.

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. On April 30, 2014, the North Carolina Business Court granted the Legacy Duke Energy Directors’ motion to dismiss the lawsuit.

It is not possible to estimate the maximum exposure of loss that may occur in connection with these lawsuits.

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.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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 18, 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 July 1, 2014, the U.S. Supreme Court granted the defendants', including Duke Energy, petition for certiorari. ~~The case will be heard during the next session of the court, which begins in October 2014.~~No date has been set for oral arguments.

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.

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 and Duke Energy Progress

DENR State Enforcement Actions

In the first quarter of 2013, environmental organizations sent notices of intent to sue to Duke Energy Carolinas and Duke Energy Progress related to alleged groundwater violations and Clean Water Act violations from coal ash basins at two of their coal-fired power plants in North Carolina. ~~The North Carolina Department of Environment and Natural Resources (DENR)~~DENR filed enforcement actions against Duke Energy Carolinas and Duke Energy Progress alleging violations of water discharge permits and North Carolina groundwater standards. The case against Duke Energy Carolinas was filed in Mecklenburg County Superior Court. The case against Duke Energy Progress was filed in Wake County Superior Court. The cases are being heard before a single judge.

On October 4, 2013, Duke Energy Carolinas, Duke Energy Progress and DENR negotiated a proposed consent ~~order.~~order covering these two plants. The consent order would have assessed civil penalties and imposed a compliance schedule requiring Duke Energy Carolinas and Duke Energy Progress to undertake monitoring and data collection activities toward making appropriate corrective action to address any substantiated violations. In light of the coal ash release that occurred at Dan River on February 2, 2014, on March 21, 2014, DENR withdrew its support of the consent orders and requested that the court proceed with the litigation.

On August 16, 2013, DENR filed an enforcement action against Duke Energy Carolinas and Duke Energy Progress related to their remaining plants in North Carolina, alleging violations of the Clean Water Act and violations of the North Carolina groundwater standards. The case against Duke Energy Carolinas was filed in Mecklenburg County Superior Court. The case against Duke Energy Progress was filed in Wake County Superior Court. Both of these cases have been assigned to the judge handling the enforcement actions discussed above. Southern Environmental Law Center (SELC), on behalf of several environmental groups, has been permitted to intervene in these cases.

It is not possible to predict any liability or estimate any damages Duke Energy Carolinas or Duke Energy Progress might incur in connection with these matters.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

North Carolina Declaratory Judgment Action

On October 10, 2012, the SELC, on behalf of the same environmental groups that were permitted to challenge the consent decrees discussed above, filed a petition with the North Carolina Environmental Management Commission (EMC) asking for a declaratory ruling seeking to clarify the application of the state’s groundwater protection rules to coal ash basins. The petition sought to change the interpretation of regulations that permitted DENR to assess the extent, cause and significance of any groundwater contamination before ordering action to eliminate the source of contamination, among other issues. Duke Energy Carolinas and Duke Energy Progress were both permitted to intervene in the matter. On December 3, 2012, the EMC affirmed this interpretation of the ~~regulations~~regulations.

On March 6, 2014, the North Carolina State Court judge overturned the ruling of the EMC holding that in the case of groundwater contamination, DENR was required to issue an order to immediately eliminate the source of the contamination before an assessment of the nature, significance and extent of the contamination or the continuing damage to the groundwater was conducted. Duke Energy Carolinas, Duke Energy Progress, and the EMC appealed the ruling in April 2014. On May 16, 2014, the North Carolina Court of Appeals denied a petition to stay the case during the appeal. On October 10, 2014, the parties were notified the case has been transferred to the North Carolina Supreme Court.

Federal Citizens Suits

There are currently five cases filed in various North Carolina federal courts contending that the state enforcement actions discussed above do not adequately address the issues raised in the notices of intent to sue related to the Riverbend, Sutton, Cape Fear, H.F. Lee and Buck plants.

On June 11, 2013, Catawba Riverkeeper Foundation, Inc. (Catawba Riverkeeper) filed a separate action in the United States Court for the Western District of North Carolina. The lawsuit contends the state enforcement action discussed above does not adequately address issues raised in Catawba Riverkeeper’s notice of intent to ~~sue.~~sue relating to the Riverbend plant. On April 11, 2014, the Court denied Catawba Riverkeeper’s objections to the Magistrate Judge’s recommendation that plaintiff’s case be dismissed as well as Duke Energy Carolinas’ motion to dismiss. The Court allowed limited discovery, after which Duke Energy Carolinas may file any renewed motions to dismiss.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

On September 12, 2013, Cape Fear River Watch, Inc., Sierra Club, and Waterkeeper Alliance filed a citizen suit in the Federal District Court for the Eastern District of North Carolina. The lawsuit alleges unpermitted discharges to surface water and groundwater ~~violations.~~violations at the Sutton plant. On June 9, 2014, the court granted Duke Energy Progress' request to dismiss the groundwater claims but rejected its request to dismiss the surface water claims.

~~On July 1, 2014, Duke Energy received 60-day notices of intent~~ In response to ~~file citizen suits from~~a motion filed by the SELC, on ~~behalf of many~~August 1, 2014, the court modified the original June 9^th order to dismiss only the plaintiff's federal law claim based on hydrologic connections at Sutton Lake. The claims related to the alleged state court violations of the ~~same environmental groups who intervened~~permits are back in the ~~state enforcement litigation described above. The notices relate~~case.

On September 3, 2014, three cases were filed by various environmental groups: (i) a citizen suit in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to ~~alleged Clean Water Act~~surface water and groundwater violations at ~~ash basins from Duke Energy Carolinas' Buck station~~the Cape Fear plant; (ii) a citizen suit in the United States Court for the Eastern District of North Carolina alleging unpermitted discharges to surface water and ~~Duke Energy Progress'~~groundwater violations at the H.F. Lee plant; and ~~Cape Fear stations.~~ (iii) a citizen suit in the United States Court for the Middle District of North Carolina alleging unpermitted discharges to surface water and groundwater violations at the Buck plant.

It is not possible to predict whether Duke Energy Carolinas or Duke Energy Progress will incur any liability or to estimate the damages, if any, they might incur in connection with these matters.

Dan River Ash Basin Grand Jury Investigation

As a result of the Dan River ash basin water release discussed above, DENR issued a Notice of Violation and Recommendation of Assessment of Civil Penalties with respect to this matter on February 28, 2014, which the company responded to on March 13, 2014. Duke Energy and certain Duke Energy employees have received subpoenas issued by the United States Attorney for the Eastern District of North Carolina in connection with a criminal investigation related to the release and all fourteen of the North Carolina facilities with ash basins and the nature of Duke Energy's contacts with DENR with respect to those facilities. This is a multidistrict investigation that also involves state law enforcement authorities.

It is not possible to predict whether Duke Energy Carolinas or Duke Energy Progress will incur any liability or to estimate the damages, if any, they might incur in connection with these matters.

Duke Energy Carolinas

New Source Review

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 New Source Review (NSR) provisions of the ~~CAA.~~Clean Air Act (CAA). The government alleges the utilities violated the CAA ~~by not obtaining permits for~~when undertaking certain maintenance and repair projects ~~undertaken~~ at certain coal plants orwithout (i) obtaining NSR permits and (ii) installing the best available emission controls for ~~SO2, NOx~~sulfur dioxide, nitrogen oxide 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 NSR permitting in cases where the projects undertaken are “routine” or otherwise do not result in a net increase in emissions.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

In 2000, the government sued Duke Energy Carolinas in the U.S. District Court in Greensboro, North ~~Carolina. The EPA claims~~Carolina, claiming NSR violations for 29 projects performed at 25 of Duke Energy Carolinas’ coal-fired ~~units violate the NSR provisions.~~units. Duke Energy Carolinas asserts the projects were routine orand not projected to increase emissions. The parties subsequently filed a stipulation ~~in which the United States dismissed~~agreeing to dismiss with prejudice ~~16 claims. In exchange, Duke Energy Carolinas dismissed certain affirmative defenses.~~all but 13 claims at 13 generating units, 11 of which have since been retired. The parties filed opposing motions for summary judgment on the remaining claims. ~~In November 2013, the~~The Court substantially denied ~~Duke Energy’s motion~~both motions for summary judgment. On March 17, 2014, the court similarly denied plaintiffs’ motion for summary judgment, except to confirm that the baseline for measuring an emissions increase at trial will be the two-year period immediately preceding each project.A Duke Energy ~~requested~~request for leave to file another motion for summary judgment on alternative ~~grounds.~~grounds, including expiration of the applicable statute of limitations, was denied. On October 24, 2014, Duke Energy Carolinas filed a motion to certify an appeal of the statute of limitations issue to the U.S. Court of Appeals for the Fourth Circuit. That motion ~~for leave remains~~is pending. ~~The 13 remaining claims involve 13 different generating units, 11 of which have already~~No trial date has been ~~retired.~~

set. 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 ~~June~~September 30, 2014, there were 9061 asserted claims for non-malignant cases with the cumulative relief sought of up to ~~$19~~$13 million, and 3523 asserted claims for malignant cases with the cumulative relief sought of up to ~~$12~~$7 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 ~~$600~~$591 million at ~~June~~September 30, 2014 and $616 million at December 31, 2013. These reserves are classified in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities on the Condensed 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. In light of the uncertainties inherent in a longer-term forecast, management does not believe they can reasonably estimate the indemnity and medical costs that might be incurred after 2033 related to such potential claims. 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~~$864 million in excess of the self-insured retention. Receivables for insurance recoveries were $616 million at September 30, 2014, and $649 million at ~~both June 30, 2014 and~~ December 31, 2013. These amounts are classified in Other within Investments and Other Assets and Receivables on the Condensed Consolidated Balance Sheets. Duke Energy Carolinas is not aware of any uncertainties regarding the legal sufficiency of insurance claims. Duke Energy Carolinas believes the insurance recovery asset is probable of recovery as the insurance carrier continues to have a strong financial strength rating.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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 Condensed Consolidated Statements of Operations and Comprehensive Income.

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. The parties reached a settlement in this matter in May 2014, and the case has been dismissed. The amount of the settlement did not have a material effect on the results of operations, cash flows or financial position of Progress Energy. As a result of the settlement of the Florida Global Case, a second suit filed in the Superior Court for Wake County, North Carolina, Progress Synfuel Holdings, Inc. et al. v. U.S. Global, LLC, has been dismissed.

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 Department of Energy 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. Duke Energy Progress and Duke Energy Florida assert damages for the period January 1, 2006 through December 31, 2010. Claims for all periods prior to 2006 have been resolved. On March 24, 2014, the U.S. Court of Federal Claims issued a judgment in favor of Duke Energy Progress and Duke Energy Florida on this matter, awarding amounts of $83 million and $21 million, respectively. The majority of the awards were recorded as a reduction to capital costs associated with construction of on-site storage facilities. ~~Receipt of the award is expected in the third quarter of 2014.~~ Duke Energy Progress and Duke Energy Florida ~~may file subsequent damage claims as they incur additional costs.~~received payment of the award in September 2014. On October 16, 2014, Duke Energy Progress and Duke Energy Florida filed a new action for costs incurred from 2011 through 2013.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Duke Energy Florida

Westinghouse Contract Litigation

On March 28, 2014 Duke Energy Florida filed a lawsuit against Westinghouse ~~Electric Company (Westinghouse)~~ in the U.S. District Court for the Western District of North Carolina. The lawsuit seeks recovery of $54 million in milestone payments in excess of work performed under the terminated EPC ~~agreement~~ for Levy as well as a determination by the court of the amounts due to Westinghouse as a result of the termination of the ~~EPC agreement. Duke Energy Florida terminated the EPC agreement on January 28, 2014.~~ EPC.

On March 31, 2014, Westinghouse filed a lawsuit against Duke Energy Florida in U.S. District Court for the Western District of Pennsylvania. The Pennsylvania lawsuit ~~alleges~~alleged damages under the EPC ~~agreement~~ in excess of $510 million for engineering and design work, costs to end supplier contracts and an alleged termination fee.

On June 9, 2014, the judge in the North Carolina case ruled that the litigation will proceed in the Western District of North Carolina. Trial is set for February 2016. It is not possible to predict the outcome of the litigation and whether Duke Energy Florida will incur any ~~further~~ liability for terminating the EPC ~~agreement~~ or to estimate the damages, if any, it might incur in connection with these matters. Ultimate resolution of these matters could have a material effect on the results of operations, financial position or cash flows of Duke Energy Florida. However, appropriate regulatory recovery will be pursued for the retail portion of any costs incurred in connection with such resolution.

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. In March 2014, a federal judge certified this matter as a class action. Trial has been set to begin on July 27, 2015. 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.

Any liability related to the lawsuit attributable to the Disposal Group will not be transferred to Dynegy upon closing of the disposal of the Midwest generation business.

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. AnThe arbitration ~~hearing~~began on October 20, 2014 and is scheduled ~~for October 2014.~~to continue into January 2015. Duke Energy Indiana cannot predict the outcome of this matter.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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, excluding asbestos related reserves. Reserves are classified on the Condensed Consolidated Balance Sheets in Other within Deferred Credits and Other Liabilities and Other within Current Liabilities. The reasonably possible range of loss for all non-asbestos related matters in excess of recorded reserves is not material.


(in millions)	June 30, 2014		December 31, 2013		September 30, 2014		December 31, 2013
Reserves for Legal Matters
Duke Energy	$	197	$	204	$	227	$	204
Progress Energy	73		78		70		78
Duke Energy Progress	10		10		9		10
Duke Energy Florida	42		43		41		43

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 Condensed 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.

In addition, the Duke Energy Registrants enter into various fixed-price, non-cancelable commitments to purchase or sell power, take-or-pay arrangements, transportation, or throughput agreements and other contracts that may or may not be recognized on their respective Condensed Consolidated Balance Sheets. Some of these arrangements may be recognized at fair value on their respective Condensed Consolidated Balance Sheets if such contracts meet the definition of a derivative and the normal purchase/normal sale (NPNS) exception does not apply. In most cases, the Duke Energy Registrants’ purchase obligation contracts contain provisions for price adjustments, minimum purchase levels, and other financial commitments.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

6. DEBT AND CREDIT FACILITIES

SUMMARY OF SIGNIFICANT DEBT ISSUANCES

The following table summarizes significant debt issuances (in millions).


				Six Months Ended June 30, 2014											Nine Months Ended September 30, 2014
Issuance Date	Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy		Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy
Unsecured Debt
April 2014^(a)	April 2024	3.750	%	$	600	$	—	$	—	$	600	April 2024	3.750	%	$	600	$	—	$	—	$	600
April 2014^(a)	April 2017	0.610	%	400		—		—		400		April 2017	0.612	%	400		—		—		400
June 2014^(b)	May 2019	10.700	%	—		—		—		108		May 2019	11.870	%	—		—		—		108
June 2014^(b)	May 2021	13.900	%	—		—		—		110		May 2021	13.680	%	—		—		—		110
Secured Debt
March 2014^(c)	March 2017	0.854	%	—		—		225		225		March 2017	0.854	%	—		—		225		225
July 2014^(d)												July 2036	5.340	%	—		—		—		129
First Mortgage Bonds
March 2014^(d)	March 2044	4.375	%	—		400		—		400
March 2014^(d)(e)	March 2017	0.430	%	—		250		—		250		March 2044	4.375	%	—		400		—		400
March 2014^(e)												March 2017	0.433	%	—		250		—		250
Total issuances				$	1,000	$	650	$	225	$	2,093				$	1,000	$	650	$	225	$	2,222


(a)	Proceeds were used to redeem $402 million of tax-exempt bonds at Duke Energy Ohio, the repayment of outstanding commercial paper and for general corporate purposes. See Note 89 for additional information related to the redemption of Duke Energy Ohio's tax-exempt bonds.


(b)	Proceeds ~~will be~~were used to repay $196 million of ~~current maturities~~debt for International Energy and for general corporate purposes.


(c)	Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Florida. Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes. See Note 1213 for further details.


(d)	Proceeds were used to fund a portion of Duke Energy's prior investment in the existing Wind Star renewables portfolio.


(e)	Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes.

CURRENT MATURITIES OF LONG-TERM DEBT

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



(in millions)	Maturity Date	Interest Rate		September 30, 2014
Unsecured Debt
Duke Energy (Parent)	April 2015	3.350	%	$	450
First Mortgage Bonds
Duke Energy Ohio	March 2015	0.373	%	150
Duke Energy Progress	April 2015	5.150	%	300
Other				256
Current maturities of long-term debt				$	1,156

5355

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

MASTER CREDIT FACILITY

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 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.



	September 30, 2014
(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
Commercial paper^(b)	(1,278		)	(784		)	(300		)	(27		)	—			(4		)	(163		)
Outstanding letters of credit	(64		)	(56		)	(4		)	(2		)	(1		)	—			(1		)
Tax-exempt bonds	(116		)	—			(35		)	—			—			—			(81		)
Available capacity	$	4,542		$	1,410		$	661		$	721		$	649		$	646		$	455


(a)	Represents the sublimit of each borrower.


(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 within Long-Term Debt Payable to Affiliated Companies in Duke Energy Carolinas' and Duke Energy Indiana’s Condensed Consolidated Balance Sheets.

7. ASSET RETIREMENT OBLIGATIONS

ASH BASINS

As a result of the Coal Ash Act and the agreement with SCDHEC discussed in Note 5, Duke Energy Carolinas and Duke Energy Progress recorded asset retirement obligations (ARO) at September 30, 2014 of $2,026 million and $1,406 million, respectively, related to closure of ash basins in North Carolina and South Carolina. The amounts recorded assume ash will retain a non-hazardous designation by the EPA.

The ARO amount is based upon estimated ash basin closure costs for each of Duke Energy's 32 ash basins located at 14 plants in North Carolina and an ash basin at a plant in South Carolina. The amount recorded represents the discounted cash flows for estimated closure costs of these ash basins based upon probability weightings of the potential closure methods as evaluated on a site by site basis. Actual costs to be incurred will be dependent upon factors that vary from site to site. The most significant factors are the method and timeframe of closure at the individual sites. Closure methods considered include removing the water from the basins and capping the ash with a synthetic barrier, excavating and relocating the ash to a lined structural fill or lined landfill, or recycling the ash for concrete or some other beneficial use. The ultimate method and timetable for closure will be in compliance with future standards set by the Coal Ash Management Commission established by the Coal Ash Act. The ARO amount will be adjusted as additional information is gained from the Coal Ash Management Commission on acceptable compliance approaches which may change management assumptions.

Asset retirement costs associated with the asset retirement obligations for operating plants and retired plants have been included in Net property, plant and equipment, and Regulatory assets, respectively, on the Condensed Consolidated Balance Sheets. As of September 30, 2014, $1,559 million and $610 million were recorded in Net property, plant and equipment for Duke Energy Carolinas and Duke Energy Progress, respectively, and $467 million and $763 million were recorded in Regulatory assets for Duke Energy Carolinas and Duke Energy Progress, respectively. The asset retirement costs recorded for Duke Energy Progress are net of $33 million of Regulatory liabilities related to cost of removal. Cost recovery for these expenditures is believed to be probable and will be pursued through the normal ratemaking process with the NCUC, PSCSC, and FERC.

The following table presents changes in the liability associated with asset retirement obligations for Duke Energy and the Subsidiary Registrants impacted by the Coal Ash Act and the agreement with SCDHEC.



(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress
Balance at December 31, 2013^(a)(b)	$	4,958		$	1,594	$	2,570		$	1,737
Accretion expense^(c)	164			71		91			63
Liabilities settled	(56		)	—		(52		)	—
Liabilities incurred in the current year^(d)	3,433			2,026		1,406			1,406
Balance at September 30, 2014	$	8,499		$	3,691	$	4,015		$	3,206

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

~~CURRENT MATURITIES OF LONG-TERM DEBT~~

(in millions) Maturity Date Interest Rate
June 30, 2014
Unsecured Debt
Duke Energy (Parent) September 2014 3.950 % $ 500
Duke Energy (Parent) April 2015 3.350 % 450
Duke Energy July 2014
15.370 %
196
First Mortgage Bonds
Duke Energy Ohio March 2015 0.370 % 150
Duke Energy Progress April 2015 5.150 % 300
Other 291
Current maturities of long-term debt $ 1,887

~~MASTER CREDIT FACILITY~~

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 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.

June 30, 2014
(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)
(1,409 ) (873 ) (300 ) (75 ) —
(11 ) (150 )
Outstanding letters of credit (64 ) (57 ) (4 ) (2 ) (1 ) —
—
Tax-exempt bonds (156 ) —
(75 ) —
—
—
(81 )
Available capacity $ 4,371
$ 1,320
$ 621
$ 673
$ 649
$ 639
$ 469


(a)	~~Represents the sublimit~~The balance as of ~~each borrower~~December 31, 2013 primarily relates to decommissioning nuclear power facilities, asbestos removal and closure of landfills at ~~June 30, 2014.~~fossil generation facilities.


(b)	The balance at December 31, 2013 includes $8 million reported in Other current liabilities on the Condensed Consolidated Balance Sheets at Duke Energy, ~~issued $450 million of commercial paper and loaned the proceeds through the money pool to Duke~~Progress Energy ~~Carolinas~~ and Duke Energy ~~Indiana. The balances are classified within Long-term Debt~~Progress.


(c)	Substantially all accretion expense for the nine months ended September 30, 2014 relates to Duke Energy's regulated electric operations from previously established asset retirement obligations and has been deferred in ~~Duke Energy Carolinas'~~accordance with regulatory accounting treatment.


(d)	Amounts relate to asset obligations recorded in the third quarter of 2014 as a result of the Coal Ash Act and ~~Duke Energy Indiana’s Condensed Consolidated Balance Sheets.~~an agreement with the SCDHEC related to the W.S Lee Steam Station.

7.8. 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			Regulated Utilities		International Energy			Commercial Power			Total
Balance at December 31, 2013
Goodwill	$	15,950	$	326	$	935		$	17,211		$	15,950	$	326		$	935		$	17,211
Accumulated impairment charges	—		—		(871		)	(871		)	—		—			(871		)	(871		)
Balance at December 31, 2013, as adjusted for accumulated impairment charges	15,950		326		64			16,340			15,950		326			64			16,340
Foreign exchange and other changes	—		3		—			3			—		(9		)	—			(9		)
Balance at June 30, 2014
Balance at September 30, 2014
Goodwill	15,950		329		935			17,214			15,950		317			935			17,202
Accumulated impairment charges	—		—		(871		)	(871		)	—		—			(871		)	(871		)
Balance at June 30, 2014, as adjusted for accumulated impairment charges	$	15,950	$	329	$	64		$	16,343
Balance at September 30, 2014, as adjusted for accumulated impairment charges											$	15,950	$	317		$	64		$	16,331

Duke Energy Ohio



(in millions)	Regulated Utilities			Commercial Power			Total
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
Balance at September 30, 2014
Goodwill	1,136			1,188			2,324
Accumulated impairment charges	(216		)	(1,188		)	(1,404		)
Balance at September 30, 2014, as adjusted for accumulated impairment charges	$	920		$	—		$	920

Progress Energy

Progress Energy's Goodwill is included in the Regulated Utilities operating segment and there are no accumulated impairment charges.

Impairment Testing

Duke Energy, Duke Energy Ohio and Progress Energy are required to perform an annual goodwill impairment test as of the same date each year and, accordingly, performs its annual impairment testing of goodwill as of August 31. Duke Energy, Duke Energy Ohio and Progress Energy update their test between annual tests if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value. As the fair value of Duke Energy, Duke Energy Ohio and Progress Energy’s reporting units exceeded their respective carrying values at the date of the annual impairment analysis, no impairment charges were recorded in the third quarter of 2014.

5457

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

~~Duke Energy Ohio~~

(in millions) Regulated Utilities
Commercial Power
Total
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
Balance at June 30, 2014
Goodwill 1,136
1,188
2,324
Accumulated impairment charges (216 ) (1,188 ) (1,404 )
Balance at June 30, 2014, as adjusted for accumulated impairment charges $ 920
$ —
$ 920

~~Progress Energy~~

~~Progress Energy's Goodwill is included in the Regulated Utilities operating segment and there are no accumulated impairment charges.~~

8.9. RELATED PARTY TRANSACTIONS

The Subsidiary Registrants engage in related party transactions, which are generally performed at cost and in accordance with the applicable state and federal commission regulations. Refer to the Condensed Consolidated Balance Sheets of the Subsidiary Registrants for balances due to or due from related parties. Material amounts related to transactions with related parties included in the Condensed Consolidated Statements of Operations and Comprehensive Income are presented in the following table.


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Duke Energy Carolinas
Corporate governance and shared service expenses^(a)	$	217	$	235	$	439	$	478	$	199	$	236	$	638	$	714
Indemnification coverages^(b)	5		6		11		11		5		5		16		16
Joint Dispatch Agreement (JDA) revenue^(c)	15		24		112		77		13		24		125		101
Joint Dispatch Agreement (JDA) expense^(c)	40		22		91		32		36		39		127		71
Progress Energy
Corporate governance and shared services provided by Duke Energy^(a)	$	200	$	111	$	378	$	273	$	182	$	54	$	560	$	327
Corporate governance and shared services provided to Duke Energy^(d)	—		22		—		50		—		24		—		74
Indemnification coverages^(b)	8		9		17		17		8		9		25		26
JDA revenue^(c)	40		22		91		32		36		39		127		71
JDA expense^(c)	15		24		112		77		13		24		125		101
Duke Energy Progress
Corporate governance and shared service expenses^(a)	$	104	$	66	$	200	$	162	$	91	$	33	$	291	$	195
Indemnification coverages^(b)	4		5		9		10		4		5		13		15
JDA revenue^(c)	40		22		91		32		36		39		127		71
JDA expense^(c)	15		24		112		77		13		24		125		101
Duke Energy Florida
Corporate governance and shared service expenses^(a)	$	97	$	45	$	178	$	111	$	91	$	20	$	269	$	131
Indemnification coverages^(b)	4		4		8		7		4		4		12		11
Duke Energy Ohio
Corporate governance and shared service expenses^(a)	$	82	$	85	$	159	$	172	$	83	$	89	$	242	$	261
Indemnification coverages^(b)	3		4		6		8		3		3		10		11
Duke Energy Indiana
Corporate governance and shared service expenses^(a)	$	94	$	101	$	199	$	200	$	94	$	113	$	293	$	313
Indemnification coverages^(b)	3		3		5		5		3		5		8		10

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~


(a)	The Subsidiary Registrants are charged their proportionate share of corporate governance and other shared services costs, primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These amounts are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.


(b)	The Subsidiary Registrants incur expenses related to certain indemnification coverages through Bison, Duke Energy’s wholly owned captive insurance subsidiary. These expenses are recorded in Operation, maintenance and other on the Condensed Consolidated Statements of Operations and Comprehensive Income.

(c)

~~Effective with the consummation of the merger between Duke Energy and Progress Energy,~~ Duke Energy Carolinas and Duke Energy ~~Progress began to~~ participate in a JDA which ~~allowed~~allows the collective dispatch of power plants between the service territories to reduce customer rates. Revenues from the sale of power under the JDA are recorded in Operating Revenues on the Condensed Consolidated Statements of Operations and Comprehensive Income. Expenses from the purchase of power under the JDA are recorded in Fuel used in electric generation and purchased power on the Condensed Consolidated Statements of Operations and Comprehensive Income.

(d)

In 2013, Progress Energy Service Company (PESC), a consolidated subsidiary of Progress Energy, charged a proportionate share of corporate governance and other costs to consolidated affiliates of Duke Energy. Corporate governance and other shared costs were primarily related to human resources, employee benefits, legal and accounting fees, as well as other third-party costs. These charges were recorded as an offset to Operation, maintenance and other in the Condensed Consolidated Statements of Operations and Comprehensive Income. Effective January 1, 2014, PESC was contributed to Duke Energy Corporate Services (DECS), a consolidated subsidiary of Duke Energy, and these costs were no longer charged out of Progress Energy. Progress Energy recorded a non-cash after-tax equity transfer related to the contribution of PESC to DECS in its Condensed Consolidated Statements of Changes in Common Stockholder's Equity during the ~~six~~nine months ended ~~June~~September 30, 2014.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

In addition to the amounts presented above, the Subsidiary Registrants record the impact on net income of other affiliate transactions, including rental of office space, participation in a money pool arrangement, other operational transactions and their proportionate share of certain charged expenses. See Note 6 to the Consolidated Financial Statements in the Annual Report on Form 10-K for more information regarding money pool. The net impact of these transactions was not material for the three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 for the Subsidiary Registrants.

See Note 1213 for information relative to sale of receivables to an affiliate consolidated by Duke Energy.

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 Condensed Consolidated Statements of Operations and Comprehensive Income. These amounts totaled net expense of $81 million and $6 million for the six months ended June 30, 2014 and 2013, respectively. Also, the amounts totaled net expense of $27 million and net revenue of $12 million for three months ended June 30, 2014 and 2013, respectively.

Because it is not a rated entity, ~~DECAM~~Duke Energy Commercial Asset Management, Inc. (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 ~~$802~~$550 million and $43 million, respectively, as of ~~June~~September 30, 2014 and December 31, 2013. These amounts are recorded in Notes payable to affiliated companies on Duke Energy Ohio’s Condensed Consolidated Balance Sheets.

As discussed in Note 6, in April 2014, Duke Energy issued $1 billion of senior unsecured notes. Proceeds from the issuances were used in part to loan approximately $400 million to DECAM, and such funds were ultimately used to redeem $402 million of tax-exempt bonds at Duke Energy Ohio. This transaction substantially completes the restructuring of Duke Energy Ohio’s capital structure to reflect appropriate debt and equity ratios for its regulated operations. The restructuring was completed in the second quarter of 2014, and resulted in the transfer of all of Duke Energy Ohio’s nonregulated generation assets, excluding Beckjord, out of its regulated public utility subsidiary.

9.10. 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 Condensed 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 ~~June~~September 30, 2014, there were no open commodity derivative instruments designated as hedges.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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’ 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.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Volumes

The tables below show information relating to volumes of 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.

June 30, 2014
Duke Energy
Duke Energy Carolinas
Progress Energy
Duke Energy Progress
Duke Energy Florida
Duke Energy Ohio
Duke Energy Indiana
Electricity (gigawatt-hours)^(a)
41,147
284
74
74
—
37,608
291
Natural gas (millions of decatherms) 683
—
323
109
214
360
—



	September 30, 2014
	Duke Energy	Duke Energy Carolinas	Progress Energy	Duke Energy Progress	Duke Energy Florida	Duke Energy Ohio	Duke Energy Indiana
Electricity (gigawatt-hours)^(a)	29,569	—	—	—	—	25,680	607
Natural gas (millions of decatherms)	659	—	319	117	202	340	—



	December 31, 2013
	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	—


(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.


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Duke Energy		Duke Energy Ohio		Duke Energy		Duke Energy Ohio		Duke Energy		Duke Energy Ohio		Duke Energy		Duke Energy Ohio
Cash flow hedges^(a)	$	764	$	—	$	798	$	—	$	764	$	—	$	798	$	—
Undesignated contracts	27		27		34		27		27		27		34		27
Total notional amount	$	791	$	27	$	832	$	27	$	791	$	27	$	832	$	27


(a)	Duke Energy includes amounts related to consolidated ~~VIEs~~Variable Interest Entities (VIEs) of $552 million at ~~June~~September 30, 2014 and $584 million at December 31, 2013.

5760

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY

The following table shows the fair value of derivatives and the line items in the Condensed Consolidated Balance Sheets where they are reported. Although derivatives subject to master netting arrangements are netted on the Condensed 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.


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Asset		Liability		Asset		Liability		Asset		Liability		Asset		Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current Liabilities: Other	$	—	$	1	$	—	$	1	$	—	$	1	$	—	$	1
Interest rate contracts
Investments and Other Assets: Other	16		—		27		—		16		—		27		—
Current Liabilities: Other	—		15		—		18		—		14		—		18
Deferred Credits and Other Liabilities: Other	—		19		—		4		—		23		—		4
Total Derivatives Designated as Hedging Instruments	16		35		27		23		16		38		27		23
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other	62		4		201		158		36		—		201		158
Current Assets: Assets Held for Sale	12		3		—		—		2		2		—		—
Investments and Other Assets: Other	11		1		215		131		9		—		215		131
Investments and Other Assets: Assets Held for Sale	12		4		—		—		9		2		—		—
Current Liabilities: Other	16		134		13		153		4		123		13		153
Current Liabilities: Liabilities Associated with Assets Held for Sale	416		563		—		—		346		445		—		—
Deferred Credits and Other Liabilities: Other	4		57		5		166		—		37		5		166
Deferred Credits and Other Liabilities: Liabilities Associated with Assets Held for Sale	248		364		—		—		148		260		—		—
Interest rate contracts
Current Liabilities: Other	—		1		—		1		—		1		—		1
Deferred Credits and Other Liabilities: Other	—		5		—		4		—		5		—		4
Total Derivatives Not Designated as Hedging Instruments	781		1,136		434		613		554		875		434		613
Total Derivatives	$	797	$	1,171	$	461	$	636	$	570	$	913	$	461	$	636

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.


	June 30, 2014												Derivative Assets
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)			Current^(a)			Non-Current^(b)			Current^(e)			Non-Current^(f)
Gross amounts recognized	$	506		$	282		$	715		$	442		$	388		$	175		$	214		$	233
Gross amounts offset	(504		)	(277		)	(576		)	(366		)	(362		)	(127		)	(179		)	(138		)
Net amount subject to master netting	2			5			139			76			26			48			35			95
Amounts not subject to master netting	—			9			6			8			—			7			—			14
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	2		$	14		$	145		$	84		$	26		$	55		$	35		$	109

5861

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)


	December 31, 2013												Derivative Liabilities
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(e)			Non-Current^(f)			Current^(g)			Non-Current^(h)			Current^(c)			Non-Current^(d)			Current^(g)			Non-Current^(h)
Gross amounts recognized	$	214		$	233		$	322		$	299		$	583		$	314		$	322		$	299
Gross amounts offset	(179		)	(138		)	(192		)	(155		)	(402		)	(203		)	(192		)	(155		)
Net amounts subject to master netting	35			95			130			144			181			111			130			144
Amounts not subject to master netting	—			14			4			11			3			13			4			11
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	35		$	109		$	134		$	155		$	184		$	124		$	134		$	155


(a)	Included in Other and Assets Held for Sale within Current Assets on the Condensed Consolidated Balance Sheet.


(b)	Included in Other and Assets Held for Sale within Investments and Other Assets on the Condensed Consolidated Balance Sheet.


(c)	Included in Other and Liabilities Associated with Assets Held for Sale within Current Liabilities on the Condensed Consolidated Balance Sheet.


(d)	Included in Other and Liabilities Associated with Assets Held for Sale within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.


(e)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.


(f)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.


(g)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.


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

The following table shows the gains and losses recognized on cash flow hedges and the line items on the Condensed Consolidated Statements of Operations where such gains and losses are included when reclassified from AOCI. Amounts for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.


	Three Months Ended June 30,					Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
(in millions)	2014			2013		2014			2013			2014			2013		2014			2013
Pretax Gains (Losses) Recorded in AOCI
Interest rate contracts	$	(11	)	$	58	$	(9	)	$	71		$	(6	)	$	—	$	(15	)	$	71
Commodity contracts	—			—		—			1			—			—		—			1
Total Pretax Gains (Losses) Recorded in AOCI	$	(11	)	$	58	$	(9	)	$	72		$	(6	)	$	—	$	(15	)	$	72
Location of Pretax Gains (Losses) Reclassified from AOCI into Earnings
Interest rate contracts
Interest expense	(4		)	—		(5		)	(1		)	(2		)	—		(7		)	(2		)
Total Pretax Gains (Losses) Reclassified from AOCI into Earnings	$	(4	)	$	—	$	(5	)	$	(1	)

There was no hedge ineffectiveness during the three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013, and no gains or losses were excluded from the assessment of hedge effectiveness during the same periods.

~~At June 30, 2014 and 2013, $57 million and $70 million, respectively, of pretax deferred net losses on interest rate cash flow hedges were included in AOCI.~~ A ~~$13~~$9 million pretax gain is expected to be recognized in earnings during the next 12 months as interest expense.

5962

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Condensed Consolidated Statements of Operations or the Condensed Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014			2013			2014			2013
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue: Regulated electric	$	3		$	1		$	(1	)	$	7		$	—		$	3		$	—		$	10
Revenue: Nonregulated electric, natural gas and other	(221		)	74			(618		)	(8		)	—			(7		)	—			(7		)
Fuel used in electric generation and purchased power - regulated	(21		)	(37		)	(14		)	(89		)	32			(68		)	18			(157		)
Fuel used in electric generation and purchased power - nonregulated	(25		)	(11		)	113			(18		)	—			(2		)	—			—
Loss from Discontinued Operations													(319		)	—			(825		)	(28		)
Interest rate contracts
Interest expense	(5		)	(5		)	(9		)	(9		)	9			(4		)	—			(13		)
Total Pretax Gains (Losses) Recognized in Earnings	$	(269	)	$	22		$	(529	)	$	(117	)	$	(278	)	$	(78	)	$	(807	)	$	(195	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	1		$	(110	)	$	(1	)	$	(5	)	$	3		$	(29	)	$	2		$	(34	)
Regulatory liabilities	(28		)	9			(1		)	4			1			6			—			10
Interest rate contracts
Regulatory assets	12			26			16			39			(7		)	12			9			51
Regulatory liabilities	28			—			28			—			(12		)	—			16			—
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	13		$	(75	)	$	42		$	38		$	(15	)	$	(11	)	$	27		$	27

DUKE ENERGY CAROLINAS

The fair values of derivative instruments were not material for the periods presented in this quarterly report.

PROGRESS ENERGY


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Asset		Liability		Asset		Liability		Asset		Liability		Asset		Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current Liabilities: Other	$	—	$	—	$	—	$	1	$	—	$	—	$	—	$	1
Deferred Credits and Other Liabilities: Other	—		—		—		4		—		—		—		4
Total Derivatives Designated as Hedging Instruments	—		—		—		5		—		—		—		5
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other	5		4		3		2		—		—		3		2
Investments and Other Assets: Other	2		1		2		1		—		—		2		1
Current Liabilities: Other	17		120		11		105		1		115		11		105
Deferred Credits and Other Liabilities: Other	4		47		4		91		1		29		4		91
Total Derivatives Not Designated as Hedging Instruments	28		172		20		199		2		144		20		199
Total Derivatives	$	28	$	172	$	20	$	204	$	2	$	144	$	20	$	204

6063

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)



	Derivative Assets
	September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(a)			Non-Current^(b)
Gross amounts recognized	$	1		$	1		$	15		$	5
Gross amounts offset	(1		)	(1		)	(13		)	(4		)
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	—		$	—		$	2		$	1


	June 30, 2014												Derivative Liabilities
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)
Gross amounts recognized	$	21		$	7		$	125		$	47		$	115		$	29		$	107		$	93
Gross amounts offset	(20		)	(5		)	(21		)	(6		)	(1		)	(1		)	(17		)	(10		)
Net amounts subject to master netting													114			28			90			83
Amounts not subject to master netting													—			—			—			4
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	1		$	2		$	104		$	41		$	114		$	28		$	90		$	87

December 31, 2013
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 amounts subject to master netting 2
1
90
83
Amounts not subject to master netting —
—
—
4
Net amounts recognized on the Condensed Consolidated Balance Sheet $ 2
$ 1
$ 90
$ 87


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


(b)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.


(c)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.


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

Gains and losses on cash flow hedges and reclassifications from AOCI were not material for the periods presented in this quarterly report.

At June 30, 2014 and 2013, $62 million and $63 million, respectively, of pretax deferred net losses on derivative instruments related to interest rate cash flow hedges were included as a component of AOCI.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Condensed Consolidated Statements of Operations and Comprehensive Income or the Condensed Consolidated Balance Sheets where the pretax gains or losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014		2013			2014		2013
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues	$	2		$	1		$	(1	)	$	7		$	1	$	3		$	—	$	10
Fuel used in electric generation and purchased power	(21		)	(37		)	(14		)	(89		)	32		(68		)	18		(157		)
Interest rate contracts
Interest expense	4			(5		)	—			(9		)	—		(4		)	—		(13		)
Total Pretax Gains (Losses) Recognized in Earnings	$	(15	)	$	(41	)	$	(15	)	$	(91	)	$	33	$	(69	)	$	18	$	(160	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	2		$	(108	)	$	—		$	(3	)	$	3	$	(31	)	$	19	$	(34	)
Interest rate contracts
Regulatory assets	12			4			16			9			—		4			—		13
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	14		$	(104	)	$	16		$	6		$	3	$	(27	)	$	19	$	(21	)

6164

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY PROGRESS


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Asset		Liability		Asset		Liability		Asset		Liability		Asset		Liability
Derivatives Designated as Hedging Instruments
Commodity contracts
Current Liabilities: Other	$	—	$	1	$	—	$	1	$	—	$	1	$	—	$	1
Total Derivatives Designated as Hedging Instruments	—		1		—		1		—		1		—		1
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other	2		2		—		—
Investments and Other Assets: Other	1		—		2		1		—		—		2		1
Current Liabilities: Other	9		54		2		40		2		39		2		40
Deferred Credits and Other Liabilities: Other	1		17		2		29		1		8		2		29
Total Derivatives Not Designated as Hedging Instruments	13		73		6		70		3		47		6		70
Total Derivatives	$	13	$	74	$	6	$	71	$	3	$	48	$	6	$	71



	Derivative Assets
	September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(a)			Non-Current^(b)
Gross amounts recognized	$	2		$	1		$	3		$	3
Gross amounts offset	(2		)	(1		)	(3		)	(3		)
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	—		$	—		$	—		$	—


	June 30, 2014												Derivative Liabilities
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)
Gross amounts recognized	$	11		$	2		$	57		$	17		$	40		$	8		$	41		$	30
Gross amounts offset	(11		)	(1		)	(11		)	(1		)	(2		)	(1		)	(3		)	(3		)
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	—		$	1		$	46		$	16		$	38		$	7		$	38		$	27

December 31, 2013
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 amounts recognized on the Condensed Consolidated Balance Sheet $ —
$ —
$ 38
$ 27


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


(b)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.


(c)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.


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

Gain and losses on cash flow hedges and reclassifications from AOCI were not material for the periods presented in this quarterly report.

6265

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Condensed Consolidated Statements of Operations and Comprehensive Income or the Condensed Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause. Amounts included in Regulatory Assets or Liabilities for interest rate contracts are reclassified to earnings as interest expense over the term of the related debt.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014			2013			2014		2013
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues	$	2		$	1		$	(1	)	$	7		$	1		$	3		$	—	$	10
Fuel used in electric generation and purchased power	(16		)	(12		)	(9		)	(29		)	13			(24		)	4		(53		)
Interest rate contracts
Interest expense	3			(3		)	—			(6		)	—			(3		)	—		(9		)
Total Pretax Gains (Losses) Recognized in Earnings	$	(11	)	$	(14	)	$	(10	)	$	(28	)	$	14		$	(24	)	$	4	$	(52	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	23		$	(43	)	$	40		$	(7	)	$	(19	)	$	(11	)	$	21	$	(18	)
Interest rate contracts
Regulatory assets	(3		)	4			—			7			—			3			—		10
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	20		$	(39	)	$	40		$	—		$	(19	)	$	(8	)	$	21	$	(8	)

DUKE ENERGY FLORIDA


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Asset		Liability		Asset		Liability		Asset		Liability		Asset		Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other	$	2	$	2	$	3	$	2	$	—	$	—	$	3	$	2
Investments and Other Assets: Other	1		1		—		—
Current Liabilities: Other	9		66		9		64		1		75		9		64
Deferred Credits and Other Liabilities: Other	3		29		2		63		1		21		2		63
Total Derivatives	$	15	$	98	$	14	$	129	$	2	$	96	$	14	$	129


	June 30, 2014												Derivative Assets
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)			Current^(a)			Non-Current^(b)			Current^(a)			Non-Current^(b)
Gross amounts recognized	$	10		$	5		$	68		$	30		$	1		$	1		$	12		$	2
Gross amounts offset	(9		)	(4		)	(10		)	(5		)	(1		)	(1		)	(10		)	(2		)
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	1		$	1		$	58		$	25		$	—		$	—		$	2		$	—

6366

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)


	December 31, 2013												Derivative Liabilities
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)
Gross amounts recognized	$	12		$	2		$	66		$	63		$	75		$	21		$	66		$	63
Gross amounts offset	(10		)	(2		)	(15		)	(7		)	(1		)	(1		)	(15		)	(7		)
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	2		$	—		$	51		$	56		$	74		$	20		$	51		$	56


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


(b)	Included in Other within Investments and Other Assets on the Condensed Balance Sheet.


(c)	Included in Other within Current Liabilities on the Condensed Balance Sheet.


(d)	Included in Other within Deferred Credits and Other Liabilities on the Condensed Balance Sheet.

Gains and losses on cash flow hedges and reclassifications from AOCI were not material for the periods presented in this quarterly report.

The following table shows the gains and losses during the year recognized on undesignated derivatives and the line items on the Condensed Consolidated Statements of Operations and Comprehensive Income or the Condensed Consolidated Balance Sheets where the pretax gains and losses were reported. Amounts included in Regulatory Assets or Liabilities for commodity contracts are reclassified to earnings to match recovery through the fuel clause.


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014		2013			2014			2013
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Operating revenues	$	—		$	—		$	—		$	—
Fuel used in electric generation and purchased power	(6		)	(25		)	(6		)	(60		)	20		(45		)	14			(105		)
Interest rate contracts
Interest expense	1			(1		)	—			(2		)	—		(1		)	—			(3		)
Total Pretax Gains (Losses) Recognized in Earnings	$	(5	)	$	(26	)	$	(6	)	$	(62	)	$	20	$	(46	)	$	14		$	(108	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	(5	)	$	(66	)	$	(24	)	$	3		$	22	$	(19	)	$	(2	)	$	(16	)
Interest rate contracts
Regulatory assets	(1		)	1			—			2			—		1			—			3
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	(6	)	$	(65	)	$	(24	)	$	5		$	22	$	(18	)	$	(2	)	$	(13	)

6467

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY OHIO


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Asset		Liability		Asset		Liability		Asset		Liability		Asset		Liability
Derivatives Not Designated as Hedging Instruments
Commodity contracts
Current Assets: Other	$	—	$	—	$	186	$	163	$	2	$	—	$	186	$	163
Current Assets: Assets Held for Sale	11		2		—		—		1		1		—		—
Investments and Other Assets: Other	—		—		202		130		—		—		202		130
Investments and Other Assets: Assets Held for Sale	10		3		—		—		9		2		—		—
Current Liabilities: Other	—		—		1		36		—		—		1		36
Current Liabilities: Liabilities Associated with Assets Held for Sale	502		634		—		—		378		484		—		—
Deferred Credits and Other Liabilities: Other	—		—		2		56		—		—		2		56
Deferred Credits and Other Liabilities: Liabilities Associated with Assets Held for Sale	318		472		—		—		174		287		—		—
Interest rate contracts
Current Liabilities: Other	—		1		—		1		—		—		—		1
Deferred Credits and Other Liabilities: Other	—		5		—		4		—		4		—		4
Total Derivatives Designated as Hedging Instruments	841		1,117		391		390		564		778		391		390
Total Derivatives	$	841	$	1,117	$	391	$	390	$	564	$	778	$	391	$	390



	Derivative Assets
	September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(e)			Non-Current^(f)
Gross amounts recognized	$	381		$	183		$	186		$	205
Gross amounts offset	(377		)	(177		)	(165		)	(132		)
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	4		$	6		$	21		$	73


	June 30, 2014												Derivative Liabilities
	Derivative Assets						Derivative Liabilities						September 30, 2014						December 31, 2013
(in millions)	Current^(a)			Non-Current^(b)			Current^(c)			Non-Current^(d)			Current^(c)			Non-Current^(d)			Current^(g)			Non-Current^(h)
Gross amounts recognized	$	513		$	328		$	637		$	480		$	485		$	293		$	199		$	186
Gross amounts offset	(504		)	(322		)	(574		)	(410		)	(419		)	(251		)	(173		)	(143		)
Net amounts subject to master netting													66			42			26			43
Amounts not subject to master netting													—			—			1			4
Net amounts recognized on the Condensed Consolidated Balance Sheet	$	9		$	6		$	63		$	70		$	66		$	42		$	27		$	47

December 31, 2013
Derivative Assets Derivative Liabilities
(in millions)
Current^(e)

Non-Current^(f)

Current^(g)

Non-Current^(h)

Gross amounts recognized $ 186
$ 205
$ 199
$ 186
Gross amounts offset (165 ) (132 ) (173 ) (143 )
Net amounts subject to master netting 21
73
26
43
Amounts not subject to master netting —
—
1
4
Net amounts recognized on the Condensed Consolidated Balance Sheet $ 21
$ 73
$ 27
$ 47


(a)	Included in Assets Held for Sale within Current Assets on the Condensed Consolidated Balance Sheet.


(b)	Included in Assets Held for Sale within Investments and Other Assets on the Condensed Consolidated Balance Sheet.


(c)	Included in Liabilities Associated with Assets Held for Sale within Current Liabilities on the Condensed Consolidated Balance Sheet.


(d)	Included in Liabilities Associated with Assets Held for Sale within Deferred Credits and Other Liabilities on the Condensed Consolidated Balance Sheet.


(e)	Included in Other within Current Assets on the Condensed Consolidated Balance Sheet.


(f)	Included in Other within Investments and Other Assets on the Condensed Consolidated Balance Sheet.


(g)	Included in Other within Current Liabilities on the Condensed Consolidated Balance Sheet.


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

Gains and losses on cash flow hedges and reclassifications from AOCI were not material for the periods presented in this quarterly report.

6568

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,					Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014			2013		2014			2013
Location of Pretax Gains and (Losses) Recognized in Earnings
Commodity contracts
Revenue, nonregulated electric, natural gas and other	$	(248	)	$	78		$	(697	)	$	(13	)
Fuel used in electric generation and purchased power	(25		)	(11		)	113			(18		)
Income (Loss) from Discontinued Operations													$	(303	)	$	3	$	(887	)	$	(28	)
Interest rate contracts
Interest expense	(1		)	(1		)	(1		)	(1		)	—			—		(1		)	(1		)
Total Pretax Gains (Losses) Recognized in Earnings	$	(274	)	$	66		$	(585	)	$	(32	)	$	(303	)	$	3	$	(888	)	$	(29	)
Location of Pretax Gains and (Losses) Recognized as Regulatory Assets or Liabilities
Commodity contracts
Regulatory assets	$	—		$	—		$	(1	)	$	—		$	—		$	—	$	(1	)	$	—
Regulatory assets	(3		)	—			—			—
Interest rate contracts
Regulatory assets	—			2			—			3			—			—		—			3
Regulatory liabilities	6			—			6			—			—			—		6			—
Total Pretax Gains (Losses) Recognized as Regulatory Assets or Liabilities	$	3		$	2		$	5		$	3		$	—		$	—	$	5		$	3

DUKE ENERGY INDIANA

The fair values of derivative instruments were not material for the periods presented in this quarterly report.

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 or (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. Amounts for Duke Energy Carolinas and Duke Energy Indiana were not material.

June 30, 2014
(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 $ 911
$ 13
$ 4
$ 9
$ 911
Fair value of collateral already posted 276
2
—
2
266
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered 76
11
4
7
80



	September 30, 2014
(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	$	688	$	107	$	38	$	69	$	688
Fair value of collateral already posted	202		—		—		—		202
Additional cash collateral or letters of credit in the event credit-risk-related contingent features were triggered	86		107		38		69		86



	December 31, 2013
(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

6669

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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. Amounts for Duke Energy Carolinas, Duke Energy Progress and Duke Energy Indiana were not material.


	June 30, 2014				December 31, 2013				September 30, 2014		December 31, 2013
(in millions)	Receivables		Payables		Receivables		Payables		Receivables		Receivables
Duke Energy
Amounts offset against net derivative positions	$	161	$	—	$	30	$	—	$	116	$	30
Amounts not offset against net derivative positions	115		—		122		—		86		122
Progress Energy
Amounts offset against net derivative positions	2		—		10		—		—		10
Duke Energy Florida
Amounts offset against net derivative positions	2		—		10		—		—		10
Duke Energy Ohio
Amounts offset against net derivative positions	158		—		19		—		116		19
Amounts not offset against net derivative positions	108		—		115		—		86		115
Duke Energy Indiana
Amounts offset against net derivative positions	—		—		—		1
Amounts not offset against net derivative positions	—		—		1		—

~~10.~~11. 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 $7 million at ~~June~~September 30, 2014 and $18 million at December 31, 2013.

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~~Nuclear Decommissioning Trust Fund (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 either classified as Cash and cash equivalents or ~~Short-term~~Short-Term investments on the Condensed Consolidated Balance Sheet based on maturity date and are available for current operations of Duke Energy’s foreign business. The fair value of these investments classified as ~~Short-term~~Short-Term investments was $44 million as of December 31, 2013.

Duke Energy classifies all other investments in debt and equity securities as long-term, unless otherwise noted.

Investment Trusts

The investments within the NDTF at Duke Energy Carolinas, Duke Energy Progress and Duke Energy Florida and the Duke Energy Progress, Duke Energy Florida and Duke Energy Indiana grantor trusts (Investment Trusts) are managed by independent investment managers with discretion to buy, sell, and invest pursuant to the objectives set forth by the trust agreements. The Duke Energy Registrants have limited oversight of the day-to-day management of these investments. As a result, the ability to hold investments in unrealized loss positions is outside the control of the Duke Energy Registrants. Accordingly, all unrealized ~~gains and~~ losses associated with debt and equity securities within the Investment Trusts are considered other-than-temporary impairments and are recognized immediately. Pursuant to regulatory accounting, substantially all 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 is included in earnings based on the criteria discussed below.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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 ~~June~~September 30, 2014 and December 31, 2013. There were no other-than-temporary impairments for debt or equity securities as of ~~June~~September 30, 2014 and December 31, 2013.

DUKE ENERGY

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


	June 30, 2014						December 31, 2013						September 30, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		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	$	—	$	—	$	70	$	—	$	—	$	110	$	—	$	—	$	74	$	—	$	—	$	110
Equity securities	2,007		14		3,873		1,813		10		3,579		1,943		28		3,825		1,813		10		3,579
Corporate debt securities	17		2		492		8		6		400		13		3		493		8		6		400
Municipal bonds	5		1		144		2		6		160		5		1		132		2		6		160
U.S. government bonds	14		3		700		7		12		730		12		4		713		7		12		730
Other debt securities	1		1		142		22		2		154		—		1		137		22		2		154
Total NDTF	$	2,044	$	21	$	5,421	$	1,852	$	36	$	5,133	$	1,973	$	37	$	5,374	$	1,852	$	36	$	5,133
Other Investments
Cash and cash equivalents	$	—	$	—	$	17	$	—	$	—	$	21	$	—	$	—	$	16	$	—	$	—	$	21
Equity securities	34		—		97		29		—		91		32		—		95		29		—		91
Corporate debt securities	2		—		66		1		1		99		2		—		68		1		1		99
Municipal bonds	4		1		82		2		2		79		3		—		82		2		2		79
U.S. government bonds	—		—		13		—		—		17		—		—		16		—		—		17
Other debt securities	1		6		110		—		8		111		1		5		96		—		8		111
Total Other Investments^(a)	$	41	$	7	$	385	$	32	$	11	$	418	$	38	$	5	$	373	$	32	$	11	$	418
Total Investments	$	2,085	$	28	$	5,806	$	1,884	$	47	$	5,551	$	2,011	$	42	$	5,747	$	1,884	$	47	$	5,551

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

The table below summarizes the maturity date for debt securities.


(in millions)	June 30, 2014		September 30, 2014
Due in one year or less	$	57	$	33
Due after one through five years	459		452
Due after five through 10 years	440		457
Due after 10 years	793		795
Total	$	1,749	$	1,737

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



	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013
Realized gains	$	28	$	72	$	90	$	135
Realized losses	51		16		57		38

6871

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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

Three Months Ended June 30, Six Months Ended June 30,
(in millions) 2014
2013
2014
2013
Realized gains $ 31
$ 32
$ 62
$ 63
Realized losses 2
15
6
22

DUKE ENERGY CAROLINAS

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


	June 30, 2014						December 31, 2013						September 30, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		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	$	—	$	—	$	33	$	—	$	—	$	42	$	—	$	—	$	39	$	—	$	—	$	42
Equity securities	1,085		8		2,156		974		6		1,964		1,046		17		2,124		974		6		1,964
Corporate debt securities	10		2		343		5		5		274		7		3		345		5		5		274
Municipal bonds	1		—		36		—		2		54		1		—		22		—		2		54
U.S. government bonds	5		1		306		3		7		354		4		2		317		3		7		354
Other debt securities	—		1		125		22		2		146		—		1		122		22		2		146
Total NDTF	$	1,101	$	12	$	2,999	$	1,004	$	22	$	2,834	$	1,058	$	23	$	2,969	$	1,004	$	22	$	2,834
Other Investments
Other debt securities	$	—	$	1	$	3	$	—	$	1	$	3	$	—	$	1	$	3	$	—	$	1	$	3
Total Other Investments^(a)	$	—	$	1	$	3	$	—	$	1	$	3	$	—	$	1	$	3	$	—	$	1	$	3
Total Investments	$	1,101	$	13	$	3,002	$	1,004	$	23	$	2,837	$	1,058	$	24	$	2,972	$	1,004	$	23	$	2,837

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

The table below summarizes the maturity date for debt securities.


(in millions)	June 30, 2014		September 30, 2014
Due in one year or less	$	24	$	2
Due after one through five years	182		171
Due after five through 10 years	243		256
Due after 10 years	364		380
Total	$	813	$	809

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


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Realized gains	$	29	$	21	$	52	$	46	$	20	$	49	$	72	$	95
Realized losses	1		6		2		10		48		1		50		11

6972

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

PROGRESS ENERGY

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


	June 30, 2014						December 31, 2013						September 30, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		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	$	—	$	—	$	37	$	—	$	—	$	68	$	—	$	—	$	35	$	—	$	—	$	68
Equity securities	922		6		1,717		839		4		1,615		897		11		1,701		839		4		1,615
Corporate debt securities	7		—		149		3		1		126		6		—		148		3		1		126
Municipal bonds	4		1		108		2		4		106		4		1		110		2		4		106
U.S. government bonds	9		2		394		4		5		376		8		2		396		4		5		376
Other debt securities	1		—		17		—		—		8		—		—		15		—		—		8
Total NDTF	$	943	$	9	$	2,422	$	848	$	14	$	2,299	$	915	$	14	$	2,405	$	848	$	14	$	2,299
Other Investments
Cash and cash equivalents	$	—	$	—	$	17	$	—	$	—	$	20	$	—	$	—	$	15	$	—	$	—	$	20
Municipal bonds	3		—		41		1		—		39		3		—		43		1		—		39
Total Other Investments^(a)	$	3	$	—	$	58	$	1	$	—	$	59	$	3	$	—	$	58	$	1	$	—	$	59
Total Investments	$	946	$	9	$	2,480	$	849	$	14	$	2,358	$	918	$	14	$	2,463	$	849	$	14	$	2,358

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

The table below summarizes the maturity date for debt securities.


(in millions)	June 30, 2014		September 30, 2014
Due in one year or less	$	24	$	21
Due after one through five years	217		218
Due after five through 10 years	141		145
Due after 10 years	327		328
Total	$	709	$	712

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


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Realized gains	$	2	$	10	$	9	$	15	$	8	$	22	$	17	$	37
Realized losses	1		7		3		9		3		11		6		20

7073

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY PROGRESS

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


	June 30, 2014						December 31, 2013						September 30, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		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	$	—	$	—	$	27	$	—	$	—	$	48	$	—	$	—	$	28	$	—	$	—	$	48
Equity securities	590		4		1,139		535		3		1,069		574		7		1,127		535		3		1,069
Corporate debt securities	5		—		94		3		1		80		4		—		95		3		1		80
Municipal bonds	4		1		106		2		4		104		4		1		108		2		4		104
U.S. government bonds	7		2		256		4		3		232		6		2		257		4		3		232
Other debt securities	1		—		10		—		—		5		—		—		8		—		—		5
Total NDTF	$	607	$	7	$	1,632	$	544	$	11	$	1,538	$	588	$	10	$	1,623	$	544	$	11	$	1,538
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	2	$	—	$	—	$	2	$	—	$	—	$	2
Total Other Investments^(a)	$	—	$	—	$	2	$	—	$	—	$	2	$	—	$	—	$	2	$	—	$	—	$	2
Total Investments	$	607	$	7	$	1,634	$	544	$	11	$	1,540	$	588	$	10	$	1,625	$	544	$	11	$	1,540

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

The table below summarizes the maturity date for debt securities.


(in millions)	June 30, 2014		September 30, 2014
Due in one year or less	$	15	$	10
Due after one through five years	141		147
Due after five through 10 years	90		94
Due after 10 years	220		217
Total	$	466	$	468

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


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Realized gains	$	1	$	6	$	7	$	8	$	4	$	7	$	11	$	15
Realized losses	—		3		2		4		2		2		4		6

7174

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY FLORIDA

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


	June 30, 2014						December 31, 2013						September 30, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		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	$	—	$	—	$	10	$	—	$	—	$	20	$	—	$	—	$	7	$	—	$	—	$	20
Equity securities	332		2		578		304		1		546		323		4		574		304		1		546
Corporate debt securities	2		—		55		—		—		46		2		—		53		—		—		46
Municipal bonds	—		—		2		—		—		2		—		—		2		—		—		2
U.S. government bonds	2		—		138		—		2		144		2		—		139		—		2		144
Other debt securities	—		—		7		—		—		3		—		—		7		—		—		3
Total NDTF	$	336	$	2	$	790	$	304	$	3	$	761	$	327	$	4	$	782	$	304	$	3	$	761
Other Investments
Cash and cash equivalents	$	—	$	—	$	2	$	—	$	—	$	3	$	—	$	—	$	—	$	—	$	—	$	3
Municipal bonds	3		—		41		1		—		39		3		—		43		1		—		39
Total Other Investments^(a)	$	3	$	—	$	43	$	1	$	—	$	42	$	3	$	—	$	43	$	1	$	—	$	42
Total Investments	$	339	$	2	$	833	$	305	$	3	$	803	$	330	$	4	$	825	$	305	$	3	$	803

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

The table below summarizes the maturity date for debt securities.


(in millions)	June 30, 2014		September 30, 2014
Due in one year or less	$	9	$	11
Due after one through five years	76		71
Due after five through 10 years	51		51
Due after 10 years	107		111
Total	$	243	$	244

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


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Realized gains	$	1	$	5	$	2	$	8	$	3	$	14	$	5	$	22
Realized losses	—		3		1		4		1		9		2		13

7275

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY INDIANA

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


	June 30, 2014						December 31, 2013						September 30, 2014						December 31, 2013
(in millions)	Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses		Estimated Fair Value		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	$	—	$	—	$	1	$	—	$	—	$	1	$	—	$	—	$	1
Equity securities	27		—		69		24		—		65		26		—		68		24		—		65
Municipal bonds	—		1		30		—		1		28		—		—		30		—		1		28
Total Other Investments^(a)	$	27	$	1	$	100	$	24	$	1	$	94	$	26	$	—	$	99	$	24	$	1	$	94
Total Investments	$	27	$	1	$	100	$	24	$	1	$	94	$	26	$	—	$	99	$	24	$	1	$	94

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

The table below summarizes the maturity date for debt securities.


(in millions)	June 30, 2014		September 30, 2014
Due in one year or less	$	1	$	1
Due after one through five years	19		18
Due after five through 10 years	7		8
Due after 10 years	3		3
Total	$	30	$	30

Realized gains and losses, which were determined on a specific identification basis, from sales of available-for-sale securities were insignificant for the three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013.

~~11.~~12. 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.

Fair value measurements are classified in three levels based on the fair value hierarchy:

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.

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.

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.

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.

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 three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013. Transfers out of Level 3 during the three and ~~six~~nine months ended ~~June~~September 30, 2014 are the result of forward commodity prices becoming observable due to the passage of time.

7376

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

Valuation methods of the primary fair value measurements disclosed below are as follows.

Investments in equity securities

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.

Investments in debt securities

Most investments in debt securities are valued using Level 2 measurements because the valuations use 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.

Commodity derivatives

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.

Interest rate derivatives

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.

Goodwill, ~~and~~ Long-lived Assets and Assets Held for Sale

See Note 78 for a discussion of the valuation of goodwill and long-lived ~~assets.~~assets and Note 2 related to the Midwest Generation Disposal Group.

DUKE ENERGY

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets. Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 9.10. See Note 1011 for additional information related to investments by major security type.


	June 30, 2014												September 30, 2014
(in millions)	Total Fair Value			Level 1			Level 2			Level 3			Total Fair Value			Level 1			Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	3,873		$	3,703		$	2		$	168		$	3,824		$	3,649		$	3		$	172
Nuclear decommissioning trust fund debt securities	1,548			374			1,174			—			1,550			388			1,162			—
Other trading and available-for-sale equity securities	98			98			—			—			96			96			—			—
Other trading and available-for-sale debt securities	294			28			246			20			284			31			238			15
Derivative assets	133			8			66			59			85			6			45			34
Total assets	5,946			4,211			1,488			247			5,839			4,170			1,448			221
Derivative liabilities	(507		)	(150		)	(320		)	(37		)	(428		)	(119		)	(253		)	(56		)
Net assets	$	5,439		$	4,061		$	1,168		$	210		$	5,411		$	4,051		$	1,195		$	165

7477

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)



	December 31, 2013
(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 debt securities	1,553			402		1,100			51
Other trading and available-for-sale equity securities	102			91		11			—
Other trading and available-for-sale debt securities	333			36		277			20
Derivative assets	145			33		70			42
Total assets	5,712			4,057		1,515			140
Derivative liabilities	(321		)	11		(303		)	(29		)
Net assets	$	5,391		$	4,068	$	1,212		$	111

The following tables provide reconciliations of beginning and ending balances of assets and liabilities measured at fair value using Level 3 measurements. Amounts included in earnings for derivatives are primarily included in Operating Revenues.



	Three Months Ended September 30, 2014
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	188		$	22		$	210
Total pretax realized or unrealized gains (losses) included in earnings	—			(33		)	(33		)
Purchases, sales, issuances and settlements:
Purchases	13			(1		)	12
Sales	(13		)	—			(13		)
Issuances	—			1			1
Transfers out of Level 3 due to observability of inputs	—			(1		)	(1		)
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			(10		)	(6		)
Balance at end of period	$	192		$	(22	)	$	170
Pretax amounts included in the Condensed Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding	$	—		$	(49	)	$	(49	)


	Three Months Ended June 30, 2014									Three Months Ended September 30, 2013
(in millions)	Investments			Derivatives (net)			Total			Investments			Derivatives (net)			Total
Balance at beginning of period	$	99		$	(14	)	$	85		$	97		$	(87	)	$	10
Total pretax realized or unrealized gains (losses) included in earnings	—			(6		)	(6		)	—			13			13
Total pretax gains included in other comprehensive income										1			—			1
Purchases, sales, issuances and settlements:
Purchases	15			51			66			2			—			2
Sales	(1		)	—			(1		)	(2		)	—			(2		)
Issuances	—			(1		)	(1		)	—			4			4
Settlements	—			(6		)	(6		)	(2		)	(3		)	(5		)
Transfers out of Level 3 due to observability of inputs	68			2			70			—			34			34
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	7			(4		)	3			1			1			2
Balance at end of period	$	188		$	22		$	210		$	97		$	(38	)	$	59
Pretax amounts included in the Condensed Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding	$	—		$	(25	)	$	(25	)

Three Months Ended June 30, 2013
(in millions) Investments
Derivatives (net)
Total
Balance at beginning of period $ 98
$ (82 ) $ 16
Total pretax realized or unrealized gains (losses) included in earnings —
(11 ) (11 )
Total pretax gains included in other comprehensive income (1 ) —
(1 )
Purchases, sales, issuances and settlements:
Purchases 3
21
24
Issuances (3 ) —
(3 )
Settlements (1 ) (9 ) (10 )
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 1
(6 ) (5 )
Balance at end of period $ 97
$ (87 ) $ 10

7578

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)



	Nine Months Ended September 30, 2014
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	98		$	13		$	111
Total pretax realized or unrealized gains (losses) included in earnings	—			(21		)	(21		)
Purchases, sales, issuances and settlements:
Purchases	29			50			79
Sales	(15		)	—			(15		)
Settlements	—			(45		)	(45		)
Transfers out of Level 3 due to observability of inputs	68			(4		)	64
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	12			(15		)	(3		)
Balance at end of period	$	192		$	(22	)	$	170
Pretax amounts included in the Condensed Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding	$	—		$	(49	)	$	(49	)


	Six Months Ended June 30, 2014									Nine Months Ended September 30, 2013
(in millions)	Investments			Derivatives (net)			Total			Investments			Derivatives (net)			Total
Balance at beginning of period	$	98		$	13		$	111		$	98		$	(85	)	$	13
Total pretax realized or unrealized gains (losses) included in earnings	—			12			12			—			(8		)	(8		)
Total pretax gains included in other comprehensive income										(1		)	—			(1		)
Purchases, sales, issuances and settlements:
Purchases	16			51			67			5			21			26
Sales	(2		)	—			(2		)	(5		)	—			(5		)
Issuances	—			(1		)	(1		)	—			9			9
Settlements	—			(45		)	(45		)	(3		)	(5		)	(8		)
Transfers out of Level 3 due to observability of inputs	68			(3		)	65			—			34			34
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	8			(5		)	3			3			(4		)	(1		)
Balance at end of period	$	188		$	22		$	210		$	97		$	(38	)	$	59
Pretax amounts included in the Condensed Consolidated Statements of Comprehensive Income related to Level 3 measurements outstanding	$	—		$	(25	)	$	(25	)

Six Months Ended June 30, 2013
(in millions) Investments
Derivatives (net)
Total
Balance at beginning of period $ 98
$ (85 ) $ 13
Total pretax realized or unrealized gains (losses) included in earnings —
(21 ) (21 )
Total pretax gains included in other comprehensive income (2 ) —
(2 )
Purchases, sales, issuances and settlements:
Purchases 3
21
24
Sales (3 ) —
(3 )
Issuances —
6
6
Settlements (1 ) (2 ) (3 )
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 2
(6 ) (4 )
Balance at end of period $ 97
$ (87 ) $ 10

DUKE ENERGY CAROLINAS

June 30, 2014
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Nuclear decommissioning trust fund equity securities $ 2,156
$ 1,986
$ 2
$ 168
Nuclear decommissioning trust fund debt securities 843
147
696
—
Other trading and available-for-sale debt securities 3
—
—
3
Total assets 3,002
2,133
698
171
Derivative liabilities (3 ) —
—
(3 )
Net assets $ 2,999
$ 2,133
$ 698
$ 168



	September 30, 2014
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Nuclear decommissioning trust fund equity securities	$	2,124	$	1,949	$	3	$	172
Nuclear decommissioning trust fund debt securities	845		150		695		—
Other trading and available-for-sale debt securities	3		—		—		3
Net assets	$	2,972	$	2,099	$	698	$	175



	December 31, 2013
(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 trading and available-for-sale debt securities	3			—		—		3
Total assets	2,837			2,047		709		81
Derivative liabilities	(2		)	—		—		(2		)
Net assets	$	2,835		$	2,047	$	709	$	79

7679

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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



	Three Months Ended September 30, 2014
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	171		$	(3	)	$	168
Purchases, sales, issuances and settlements:
Purchases	13			—			13
Sales	(13		)	—			(13		)
Settlements	—			3			3
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	4			—			4
Balance at end of period	$	175		$	—		$	175



	Three Months Ended September 30, 2013
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	74		$	(4	)	$	70
Purchases, sales, issuances and settlements:
Purchases	2			—			2
Sales	(2		)	—			(2		)
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	1			—			1
Balance at end of period	$	75		$	(4	)	$	71



	Nine Months Ended September 30, 2014
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	81		$	(2	)	$	79
Purchases, sales, issuances and settlements:
Purchases	29			—			29
Sales	(15		)	—			(15		)
Settlements	—			2			2
Transfers out of Level 3 due to observability of inputs	68			—			68
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	12			—			12
Balance at end of period	$	175		$	—		$	175



	Nine Months Ended September 30, 2013
(in millions)	Investments			Derivatives (net)			Total
Balance at beginning of period	$	72		$	(12	)	$	60
Purchases, sales, issuances and settlements:
Purchases	5			—			5
Sales	(5		)	—			(5		)
Settlements	—			8			8
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	3			—			3
Balance at end of period	$	75		$	(4	)	$	71

Three Months Ended June 30, 2014
(in millions) Investments
Derivatives (net)
Total
Balance at beginning of period $ 82
$ (4 ) $ 78
Purchases, sales, issuances and settlements:
Purchases 15
—
15
Sales (1 ) —
(1 )
Settlements —
1
1
Transfers out of Level 3 due to observability of inputs 68
—
68
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 7
—
7
Balance at end of period $ 171
$ (3 ) $ 168

Three Months Ended June 30, 2013
(in millions) Investments
Derivatives (net)
Total
Balance at beginning of period $ 73
$ (5 ) $ 68
Purchases, sales, issuances and settlements:
Purchases 3
—
3
Sales (3 ) —
(3 )
Settlements —
1
1
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 1
—
1
Balance at end of period $ 74
$ (4 ) $ 70

Six Months Ended June 30, 2014
(in millions) Investments
Derivatives (net)
Total
Balance at beginning of period $ 81
$ (2 ) $ 79
Purchases, sales, issuances and settlements:
Purchases 16
—
16
Sales (2 ) —
(2 )
Settlements —
(1 ) (1 )
Transfers out of Level 3 due to observability of inputs 68
—
68
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 8
—
8
Balance at end of period $ 171
$ (3 ) $ 168

Six Months Ended June 30, 2013
(in millions) Investments
Derivatives (net)
Total
Balance at beginning of period $ 72
$ (12 ) $ 60
Purchases, sales, issuances and settlements:
Purchases 3
—
3
Sales (3 ) —
(3 )
Settlements —
8
8
Total gains (losses) included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 2
—
2
Balance at end of period $ 74
$ (4 ) $ 70
PROGRESS ENERGY

7780

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

~~PROGRESS ENERGY~~

June 30, 2014
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Nuclear decommissioning trust fund equity securities $ 1,717
$ 1,717
$ —
$ —
Nuclear decommissioning trust fund debt securities 705
227
478
—
Other trading and available-for-sale debt securities 58
16
42
—
Derivative assets 3
—
3
—
Total assets 2,483
1,960
523
—
Derivative liabilities (147 ) —
(147 ) —
Net assets $ 2,336
$ 1,960
$ 376
$ —



	September 30, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	1,700		$	1,700	$	—		$	—
Nuclear decommissioning trust fund debt securities	705			238		467			—
Other trading and available-for-sale debt securities	58			15		43			—
Total assets	2,463			1,953		510			—
Derivative liabilities	(142		)	—		(142		)	—
Net assets	$	2,321		$	1,953	$	368		$	—



	December 31, 2013
(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	677			233		444			—
Other trading and available-for-sale debt securities	58			19		39			—
Derivative assets	3			—		3			—
Total assets	2,353			1,867		486			—
Derivative liabilities	(187		)	—		(187		)	—
Net assets	$	2,166		$	1,867	$	299		$	—

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


	Derivatives (net)												Derivatives (net)
	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013			2014			2013			2014		2013
Balance at beginning of period	$	(3	)	$	(31	)	$	—		$	(38	)	$	—		$	(35	)	$	—	$	(38	)
Total pretax realized or unrealized gains included in earnings	3			—			—			—
Purchases, sales, issuances and settlements:
Issuances	—			1			—			7			—			2			—		10
Transfers out of Level 3 due to observability of inputs	2			—			2			—			2			34			—		34
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(2		)	(5		)	(2		)	(4		)	(2		)	(1		)	—		(6		)
Balance at end of period	$	—		$	(35	)	$	—		$	(35	)	$	—		$	—		$	—	$	—

7881

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY PROGRESS


	June 30, 2014										September 30, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3		Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	1,139		$	1,139	$	—		$	—	$	1,126		$	1,126	$	—		$	—
Nuclear decommissioning trust fund debt securities	493			149		344			—		497			155		342			—
Other trading and available-for-sale debt securities	2			2		—			—		2			2		—			—
Derivative assets	1			—		1			—
Total assets	1,635			1,290		345			—		1,625			1,283		342			—
Derivative liabilities	(62		)	—		(62		)	—		(45		)	—		(45		)	—
Net assets	$	1,573		$	1,290	$	283		$	—	$	1,580		$	1,283	$	297		$	—



	December 31, 2013
(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	470			137		333			—
Other trading and available-for-sale debt securities	3			3		—			—
Derivative assets	1			—		1			—
Total assets	1,543			1,209		334			—
Derivative liabilities	(66		)	—		(66		)	—
Net assets	$	1,477		$	1,209	$	268		$	—

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

Derivatives (net)
Three Months Ended June 30, Six Months Ended June 30,
(in millions) 2014
2013
2014
2013
Balance at beginning of period $ (3 ) $ (31 ) $ —
$ (38 )
Total pretax realized or unrealized gains included in earnings 3
—
—
—
Purchases, sales, issuances and settlements:
Issuances —
1
—
7
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities —
(5 ) —
(4 )
Balance at end of period $ —
$ (35 ) $ —
$ (35 )

~~DUKE ENERGY FLORIDA~~

~~The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 9. See Note 10~~ ~~for additional information related to investments by major security type.~~

June 30, 2014
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Nuclear decommissioning trust fund equity securities $ 578
$ 578
$ —
$ —
Nuclear decommissioning trust fund debt securities and other 212
78
134
—
Other trading and available-for-sale debt securities and other 43
1
42
—
Derivative assets 2
—
2
—
Total assets 835
657
178
—
Derivative liabilities (85 ) —
(85 ) —
Net assets $ 750
$ 657
$ 93
$ —



	Derivatives (net)
	Three Months Ended September 30,					Nine Months Ended September 30,
(in millions)	2014		2013			2014		2013
Balance at beginning of period	$	—	$	(35	)	$	—	$	(38	)
Purchases, sales, issuances and settlements:
Issuances	—		—			—		9
Settlements	—		2			—		—
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	—		(1		)	—		(5		)
Transfers out of Level 3 due to observability of inputs	—		34			—		34
Balance at end of period	$	—	$	—		$	—	$	—

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

December 31, 2013
(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 40
2
38
—
Derivative assets 1
—
1
—
Total assets 801
644
157
—
Derivative liabilities (116 ) —
(116 ) —
Net assets $ 685
$ 644
$ 41
$ —

~~DUKE ENERGY OHIO~~

June 30, 2014
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Derivative assets $ 18
$ —
$ 11
$ 7
Derivative liabilities (294 ) (145 ) (114 ) (35 )
Net assets (liabilities) $ (276 ) $ (145 ) $ (103 ) $ (28 )

December 31, 2013
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Derivative assets $ 96
$ 50
$ 21
$ 25
Derivative liabilities (95 ) (1 ) (65 ) (29 )
Net assets (liabilities) $ 1
$ 49
$ (44 ) $ (4 )

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

Derivatives (net)
Three Months Ended June 30, Six Months Ended June 30,
(in millions) 2014
2013
2014
2013
Balance at beginning of period $ (19 ) $ (5 ) $ (4 ) $ (6 )
Total pretax realized or unrealized gains (losses) included in earnings (13 ) (14 ) (19 ) (10 )
Purchases, sales, issuances and settlements:
Purchases 1
1
1
1
Settlements —
—
(4 ) (3 )
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities 2
(1 ) 2
(1 )
Transfers out of Level 3 due to observability of inputs 1
—
(4 ) —
Balance at end of period $ (28 ) $ (19 ) $ (28 ) $ (19 )
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at June 30, 2014

$ (27 )

8082

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

DUKE ENERGY ~~INDIANA~~FLORIDA



	September 30, 2014
(in millions)	Total Fair Value			Level 1		Level 2			Level 3
Nuclear decommissioning trust fund equity securities	$	574		$	574	$	—		$	—
Nuclear decommissioning trust fund debt securities and other	208			83		125			—
Other trading and available-for-sale debt securities and other	43			—		43			—
Derivative assets	3			—		3			—
Total assets	828			657		171			—
Derivative liabilities	(97		)	—		(97		)	—
Net assets	$	731		$	657	$	74		$	—



	December 31, 2013
(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	40			2		38			—
Derivative assets	1			—		1			—
Total assets	801			644		157			—
Derivative liabilities	(116		)	—		(116		)	—
Net assets	$	685		$	644	$	41		$	—

June 30, 2014
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Available-for-sale equity securities $ 70
$ 70
$ —
$ —
Available-for-sale debt securities 30
—
30
—
Derivative assets 45
—
—
45
Net assets $ 145
$ 70
$ 30
$ 45

December 31, 2013
(in millions) Total Fair Value
Level 1
Level 2
Level 3
Available-for-sale equity securities $ 65
$ 65
$ —
$ —
Available-for-sale debt securities 29
—
29
—
Derivative assets 12
—
—
12
Net assets $ 106
$ 65
$ 29
$ 12
DUKE ENERGY OHIO

The following tables provide ~~reconciliations of beginning and ending~~recorded balances offor assets and liabilities measured at fair value ~~using Level 3 measurements.~~on a recurring basis on the Condensed Consolidated Balance Sheets.Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 10.



	September 30, 2014
(in millions)	Total Fair Value			Level 1			Level 2			Level 3
Derivative assets	$	7		$	—		$	3		$	4
Derivative liabilities	(221		)	(114		)	(48		)	(59		)
Net assets (liabilities)	$	(214	)	$	(114	)	$	(45	)	$	(55	)

Derivatives (net)
Three Months Ended June 30, Six Months Ended June 30,
(in millions) 2014
2013
2014
2013
Balance at beginning of period $ 7
$ 4
$ 12
$ 10
Total pretax realized or unrealized gains (losses) included in earnings —
7
27
2
Purchases, sales, issuances and settlements:
Purchases 49
20
49
—
Sales —
—
—
20
Settlements (7 ) (13 ) (38 ) (13 )
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities (4 ) —
(5 ) (1 )
Balance at end of period $ 45
$ 18
$ 45
$ 18



	December 31, 2013
(in millions)	Total Fair Value			Level 1			Level 2			Level 3
Derivative assets	$	96		$	50		$	21		$	25
Derivative liabilities	(95		)	(1		)	(65		)	(29		)
Net assets (liabilities)	$	1		$	49		$	(44	)	$	(4	)

8183

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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



	Derivatives (net)
	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
Balance at beginning of period	$	(28	)	$	(19	)	$	(4	)	$	(6	)
Total pretax realized or unrealized gains (losses) included in earnings	(24		)	11			(43		)	(4		)
Purchases, sales, issuances and settlements:
Purchases	—			—			1			1
Settlements	(2		)	2			(6		)	—
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(1		)	—			1			3
Transfers out of Level 3 due to observability of inputs	—			—			(4		)	—
Balance at end of period	$	(55	)	$	(6	)	$	(55	)	$	(6	)
Pretax amounts included in the Condensed Consolidated Statements of Operations and Comprehensive Income related to Level 3 measurements outstanding at June 30, 2014							$	(52	)

DUKE ENERGY INDIANA

The following tables provide recorded balances for assets and liabilities measured at fair value on a recurring basis on the Condensed Consolidated Balance Sheets.Derivative amounts in the table below exclude cash collateral, which is disclosed in Note 10. See Note 11 for additional information related to investments by major security type.



	September 30, 2014
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Available-for-sale equity securities	$	69	$	69	$	—	$	—
Available-for-sale debt securities	30		—		30		—
Derivative assets	23		1		—		22
Net assets	$	122	$	70	$	30	$	22



	December 31, 2013
(in millions)	Total Fair Value		Level 1		Level 2		Level 3
Available-for-sale equity securities	$	65	$	65	$	—	$	—
Available-for-sale debt securities	29		—		29		—
Derivative assets	12		—		—		12
Net assets	$	106	$	65	$	29	$	12

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



	Derivatives (net)
	Three Months Ended September 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
Balance at beginning of period	$	45		$	18		$	12		$	10
Total pretax realized or unrealized gains (losses) included in earnings	(13		)	3			14			5
Purchases, sales, issuances and settlements:
Purchases	—			—			49			20
Settlements	—			(10		)	(38		)	(23		)
Total gains included on the Condensed Consolidated Balance Sheet as regulatory assets or liabilities	(10		)	3			(15		)	2
Balance at end of period	$	22		$	14		$	22		$	14

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

QUANTITATIVE DISCLOSURES ABOUT UNOBSERVABLE INPUTS

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



	September 30, 2014
Investment Type	Fair Value (in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy
Natural gas contracts	$	(33	)	Discounted cash flow	Forward natural gas curves - price per MMBtu	$	2.45		-	$	4.66
Financial transmission rights (FTRs)	22			RTO auction pricing	FTR price - per MWh	(2.47		)	-	12.92
Electricity contracts	(2		)	Discounted cash flow	Forward electricity curves - price per MWh	25.18			-	59.17
Commodity capacity option contracts	5			Discounted cash flow	Forward capacity option curves - price per MW day	28.60			-	189.25
Reserves	(14		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	(22	)
Duke Energy Ohio
Electricity contracts	$	(10	)	Discounted cash flow	Forward electricity curves - price per MWh	25.35			-	59.60
Natural gas contracts	(33		)	Discounted cash flow	Forward natural gas curves - price per MMBtu	2.45			-	4.66
Reserves	(12		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	(55	)
Duke Energy Indiana
FTRs	$	22		RTO auction pricing	FTR price - per MWh	(2.47		)	-	12.92


	June 30, 2014											December 31, 2013
Investment Type	Fair Value (in millions)			Valuation Technique	Unobservable Input	Range						Fair Value (in millions)			Valuation Technique	Unobservable Input	Range
Duke Energy
Natural gas contracts	$	(1	)	Discounted cash flow	Forward natural gas curves - price per MMBtu	$	2.92		-	$	4.71	$	(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)	45			RTO auction pricing	FTR price - per MWh	(4.53		)	-	60.90		12			RTO auction pricing	FTR price - per MWh	(0.30		)	-	13.80
Electricity contracts	(9		)	Discounted cash flow	Forward electricity curves - price per MWh	25.10			-	62.77		23			Discounted cash flow	Forward electricity curves - price per MWh	20.77			-	58.90
Commodity capacity option contracts	4			Discounted cash flow	Forward capacity option curves - price per MW day	27.65			-	161.10		4			Discounted cash flow	Forward capacity option curves - price per MW day	30.40			-	165.10
Reserves	(17		)		Bid-ask spreads, implied volatility, probability of default							(22		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	22										$	13
Duke Energy Carolinas
Electricity contracts	$	(3	)	Discounted cash flow	Forward electricity curves - price per MWh	36.37			-	62.54
FERC mitigation power sale agreements												$	(2	)	Discounted cash flow	Forward electricity curves - price per MWh	25.79			-	52.38
Duke Energy Ohio
Electricity contracts	$	(13	)	Discounted cash flow	Forward electricity curves - price per MWh	25.55			-	65.42		$	18		Discounted cash flow	Forward electricity curves - price per MWh	20.77			-	58.90
Natural gas contracts	(1		)	Discounted cash flow	Forward natural gas curves - price per MMBtu	2.92			-	4.71		(2		)	Discounted cash flow	Forward natural gas curves - price per MMBtu	3.07			-	5.37
Reserves	(14		)		Bid-ask spreads, implied volatility, probability of default							(20		)		Bid-ask spreads, implied volatility, probability of default
Total Level 3 derivatives	$	(28	)									$	(4	)
Duke Energy Indiana
FTRs	$	45		RTO auction pricing	FTR price - per MWh	(4.53		)	-	60.90		$	12		RTO auction pricing	FTR price - per MWh	(0.30		)	-	13.80

December 31, 2013
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 MWh (0.30 ) - 13.80
Electricity contracts 23
Discounted cash flow Forward electricity curves - price per MWh 20.77
- 58.90
Commodity capacity option contracts 4
Discounted cash flow Forward capacity option curves - price per MW day 30.40
- 165.10
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
- 58.90
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 (0.30 ) - 13.80

8285

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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.


	June 30, 2014				December 31, 2013				September 30, 2014				December 31, 2013
(in millions)	Book Value		Fair Value		Book Value		Fair Value		Book Value		Fair Value		Book Value		Fair Value
Duke Energy	$	40,593	$	44,558	$	40,256	$	42,592	$	39,858	$	43,602	$	40,256	$	42,592
Duke Energy Carolinas	8,435		9,510		8,436		9,123		8,394		9,426		8,436		9,123
Progress Energy	14,518		16,387		14,115		15,234		14,512		16,305		14,115		15,234
Duke Energy Progress	5,717		6,045		5,235		5,323		5,716		6,013		5,235		5,323
Duke Energy Florida	5,107		5,892		4,886		5,408		5,102		5,867		4,886		5,408
Duke Energy Ohio	1,784		1,983		2,188		2,237		1,783		1,967		2,188		2,237
Duke Energy Indiana	3,795		4,374		3,796		4,171		3,795		4,356		3,796		4,171

At both ~~June~~September 30, 2014 and December 31, 2013, the fair value of cash and cash equivalents, accounts and notes receivable, accounts payable, notes payable and commercial paper, and non-recourse notes payable of variable interest entities are not materially different from their carrying amounts because of the short-term nature of these instruments and/or because the stated rates approximate market rates.

~~12.~~13. 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 consolidated VIEs during the ~~six~~nine months ended ~~June~~September 30, 2014 and the year ended December 31, 2013, or is expected to be provided in the future, that was not previously contractually required.

8386

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

CONSOLIDATED VIEs

The ~~table~~tables below ~~shows~~show VIEs consolidated and how these entities impact the Condensed Consolidated Balance Sheets.


	June 30, 2014																	September 30, 2014
	Duke Energy																	Duke Energy
	Duke Energy Carolinas		Duke Energy Progress		Duke Energy Florida													Duke Energy Carolinas		Duke Energy Progress		Duke Energy Florida
(in millions)	DERF		DEPR		DEFR		CRC		Renewables			Other			Total			DERF		DEPR		DEFR		CRC		Renewables			Other			Total
ASSETS
Current Assets
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	$	704	$	471	$	403	$	506	$	17		$	19		$	2,120		$	695	$	474	$	403	$	465	$	12		$	20		$	2,069
Other	—		—		—		—		115			12			127			—		—		—		—		141			13			154
Investments and Other Assets
Other	—		—		—		—		30			39			69			—		—		—		—		29			34			63
Property, Plant and Equipment
Property, plant and equipment, cost^(a)	—		—		—		—		1,856			18			1,874			—		—		—		—		1,856			18			1,874
Accumulated depreciation and amortization	—		—		—		—		(214		)	(5		)	(219		)	—		—		—		—		(232		)	(5		)	(237		)
Regulatory Assets and Deferred Debits
Other	1		—		1		—		33			—			35			1		—		1		—		35			—			37
Total assets	$	705	$	471	$	404	$	506	$	1,837		$	83		$	4,006		$	696	$	474	$	404	$	465	$	1,841		$	80		$	3,960
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	—	$	—	$	—	$	—	$	3		$	—		$	3		$	—	$	—	$	—	$	—	$	2		$	—		$	2
Taxes accrued	—		—		—		—		4			—			4			—		—		—		—		6			—			6
Current maturities of long-term debt	—		—		—		—		64			16			80			—		—		—		—		67			16			83
Other	—		—		—		—		17			11			28			—		—		—		—		26			12			38
Long-term Debt^(b)	400		300		225		325		863			26			2,139
Long-Term Debt(b)																		400		300		225		325		989			21			2,260
Deferred Credits and Other Liabilities
Deferred income taxes	—		—		—		—		292			—			292			—		—		—		—		292			—			292
Asset retirement obligations	—		—		—		—		30			—			30			—		—		—		—		31			—			31
Other	—		—		—		—		33			9			42			—		—		—		—		33			10			43
Total liabilities	$	400	$	300	$	225	$	325	$	1,306		$	62		$	2,618		$	400	$	300	$	225	$	325	$	1,446		$	59		$	2,755
Net assets of consolidated variable interest entities	$	305	$	171	$	179	$	181	$	531		$	21		$	1,388		$	296	$	174	$	179	$	140	$	395		$	21		$	1,205

(a) Restricted as collateral for non-recourse debt of VIEs.

(b) Non-recourse to the general assets of the applicable registrant.

8487

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)


	December 31, 2013															December 31, 2013
	Duke Energy															Duke Energy
	Duke Energy Carolinas		Duke Energy Progress													Duke Energy Carolinas		Duke Energy Progress
(in millions)	DERF		DEPR		CRC		Renewables			Other			Total			DERF		DEPR		CRC		Renewables			Other			Total
ASSETS
Current Assets
Restricted receivables of variable interest entities (net of allowance for doubtful accounts)	$	673	$	416	$	595	$	18		$	17		$	1,719		$	673	$	416	$	595	$	18		$	17		$	1,719
Other	—		—		—		89			12			101			—		—		—		89			12			101
Investments and Other Assets
Other	—		—		—		29			51			80			—		—		—		29			51			80
Property, Plant and Equipment
Property, plant and equipment, cost^(a)	—		—		—		1,662			18			1,680			—		—		—		1,662			18			1,680
Accumulated depreciation and amortization	—		—		—		(170		)	(5		)	(175		)	—		—		—		(170		)	(5		)	(175		)
Regulatory Assets and Deferred Debits
Other	1		1		—		34			—			36			1		1		—		34			—			36
Total assets	$	674	$	417	$	595	$	1,662		$	93		$	3,441		$	674	$	417	$	595	$	1,662		$	93		$	3,441
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	—	$	—	$	—	$	2		$	—		$	2		$	—	$	—	$	—	$	2		$	—		$	2
Taxes accrued	—		—		—		10			—			10			—		—		—		10			—			10
Current maturities of long-term debt	—		—		—		66			14			80			—		—		—		66			14			80
Other	—		—		—		17			10			27			—		—		—		17			10			27
Long-term Debt^(b)	400		300		325		907			34			1,966
Long-Term Debt(b)																400		300		325		907			34			1,966
Deferred Credits and Other Liabilities
Deferred income taxes	—		—		—		290			—			290			—		—		—		290			—			290
Asset retirement obligations	—		—		—		26			—			26			—		—		—		26			—			26
Other	1		—		—		17			13			31			1		—		—		17			13			31
Total liabilities	$	401	$	300	$	325	$	1,335		$	71		$	2,432		$	401	$	300	$	325	$	1,335		$	71		$	2,432
Net assets of consolidated variable interest entities	$	273	$	117	$	270	$	327		$	22		$	1,009		$	273	$	117	$	270	$	327		$	22		$	1,009

(a) Restricted as collateral for non-recourse debt of VIEs.

(b) Non-recourse to the general assets of the applicable registrant.

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 / DEPR / DEFR

~~On a daily basis,~~ Duke Energy Receivables Finance Company, LLC (DERF), aDuke Energy Progress Receivables Company, LLC (DEPR), and Duke Energy Florida Receivables Company, LLC (DEFR) are bankruptcy remote, special purpose ~~subsidiary~~subsidiaries of Duke Energy Carolinas, ~~buys~~Duke Energy Progress, and Duke Energy Florida, respectively. On a daily basis, DERF, DEPR, and DEFR buy certain accounts receivable arising from the sale of electricity and/or related services from Duke Energy ~~Carolinas.~~Carolinas, Duke Energy Progress, and Duke Energy Florida. DERF, ~~is a~~DEPR, and DEFR are wholly owned limited liability ~~company~~companies with a separate legal existence from ~~its parent,~~their parents, and ~~its~~their assets are not generally available to creditors of Duke Energy ~~Carolinas.~~Carolinas, Duke Energy Progress, and Duke Energy Florida. DERF, ~~borrows $400 million~~DEPR, and DEFR borrow amounts under a credit ~~facility~~facilities to buy the receivables. ~~Borrowing is~~Borrowings are limited to the amount of qualified receivables sold, which is expected to be in excess of the credit ~~facility.~~facilities. The credit ~~facility expires in October 2016 and is~~facilities are reflected on the Condensed Consolidated Balance Sheets as ~~Long-term~~Long-Term Debt. The secured credit ~~facility was~~facilities were 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, isDEPR, and DEFR are the decisions made to manage delinquent receivables. Duke Energy Carolinas, ~~consolidates~~Duke Energy Progress, and Duke Energy Florida consolidate DERF, DEPR, and DEFR, respectively, as ~~it makes~~they make those decisions.

8588

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

~~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,The following table outlines amounts 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 excessexpiration dates of the credit facility. The credit facility expires in December 2016 and is reflected on the Condensed 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.facilities.

~~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.~~

~~DEFR~~

On a daily basis, Duke Energy Florida Receivables Company, LLC (DEFR), a bankruptcy remote, special purpose subsidiary of Duke Energy Florida formed in 2014, buys certain accounts receivable arising from the sale of electricity and/or related services from Duke Energy Florida. DEFR 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 Florida. DEFR borrows $225 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 the credit facility. The credit facility expires in March 2017 and is reflected on the Condensed 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 DEFR is the decisions made to manage delinquent receivables. Duke Energy Florida consolidates DEFR as it makes those decisions.~~



	DERF		DEPR		DEFR
Credit facility amount (in millions)	$	400	$	300	$	225
Expiration date	October 2016		December 2016		March 2017

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. The 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 receivables 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 three or ~~six~~nine months ended ~~June~~September 30, 2014 and 2013, respectively. ~~Borrowings fluctuate based on~~Borrowing is limited to the amount of qualified receivables ~~sold.~~sold, which is expected to be in excess of the credit facility. The credit facility expires in November ~~2016.~~

~~The secured credit facility~~2016 and is reflected on the Condensed Consolidated Balance Sheets as ~~Long-term~~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.

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 consolidates the entities as it makes all of these decisions.

NON-CONSOLIDATED VIEs

The tables below show VIEs not consolidated and how these entities impact the Condensed Consolidated Balance Sheets.


	June 30, 2014										September 30, 2014
	Duke Energy						Duke Energy Ohio		Duke Energy Indiana		Duke Energy							Duke Energy Ohio		Duke Energy Indiana
(in millions)	Renewables		Other		Total		Duke Energy Ohio		Duke Energy Indiana		Renewables		Other			Total		Duke Energy Ohio		Duke Energy Indiana
Receivables	$	—	$	—	$	—	$	68	$	98	$	—	$	—		$	—	$	49	$	76
Investments in equity method unconsolidated affiliates	152		26		178		—		—		149		3			152		—		$	—
Investments and other assets	—		4		4		—		—		—		4			4		—		—
Total assets	$	152	$	30	$	182	$	68	$	98	$	149	$	7		$	156	$	49	$	76
Other current liabilities	$	—	$	3	$	3	$	—	$	—	$	—	$	2		$	2	$	—	$	—
Deferred credits and other liabilities	—		14		14		—		—		—		14			14		—		—
Total liabilities	$	—	$	17	$	17	$	—	$	—	$	—	$	16		$	16	$	—	$	—
Net assets (liabilities)	$	152	$	13	$	165	$	68	$	98	$	149	$	(9	)	$	140	$	49	$	76

8689

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)



	December 31, 2013
	Duke Energy						Duke Energy Ohio		Duke Energy Indiana
(in millions)	Renewables		Other		Total		Duke Energy Ohio		Duke Energy Indiana
Receivables	$	—	$	—	$	—	$	114	$	143
Investments in equity method unconsolidated affiliates	153		60		213		—		—
Intangibles, net	—		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

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 OVEC, which is discussed below, and various guarantees (See Note 5), reflected in the table above as Deferred credits and other liabilities.

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.

Other

At December 31, 2013, 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. The initial carrying value of this contract was recorded as an intangible asset when Duke Energy acquired Cinergy in April 2006. The ~~OVEC~~carrying amount was reclassified to Assets held for sale in conjunction with the planned disposition of the Midwest Generation business in the first quarter of 2014. In the second quarter of 2014, Duke Energy Ohio removed OVEC from the disposal group as it has requested cost-based recovery of OVEC, ~~in its 2014 Electric Security Plan (ESP) application.~~including this intangible asset, was fully impaired at September 30, 2014.

CRC

See discussion under Consolidated VIEs for additional information related to CRC.

Amounts included in Receivables in the above table for Duke Energy Ohio and Duke Energy Indiana reflect their retained interest in receivables sold to CRC. These subordinated notes held by Duke Energy Ohio and Duke Energy Indiana are stated at fair value and are classified within Receivables in their Condensed 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 bases 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 fair value are detailed in the following table.



	Duke Energy Ohio				Duke Energy Indiana
	2014		2013		2014		2013
Anticipated credit loss ratio	0.6	%	0.6	%	0.3	%	0.3	%
Discount rate	1.2	%	1.2	%	1.2	%	1.2	%
Receivable turnover rate	12.8	%	12.8	%	10.5	%	10.3	%

8790

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The following table shows the gross and net receivables sold.


	Duke Energy Ohio				Duke Energy Indiana				Duke Energy Ohio				Duke Energy Indiana
(in millions)	June 30, 2014		December 31, 2013		June 30, 2014		December 31, 2013		September 30, 2014		December 31, 2013		September 30, 2014		December 31, 2013
Receivables sold	$	236	$	290	$	311	$	340	$	216	$	290	$	287	$	340
Less: Retained interests	68		114		98		143		49		114		76		143
Net receivables sold	$	168	$	176	$	213	$	197	$	167	$	176	$	211	$	197

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


	Duke Energy Ohio										Duke Energy Indiana										Duke Energy Ohio								Duke Energy Indiana
	Three Months Ended June 30,					Six Months Ended June 30,					Three Months Ended June 30,					Six Months Ended June 30,					Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014			2013		2014			2013		2014			2013		2014			2013		2014		2013		2014		2013		2014		2013		2014		2013
Sales
Receivables sold	$	487		$	512	$	1,228		$	1,150	$	679		$	702	$	1,434		$	1,449	$	477	$	514	$	1,705	$	1,664	$	739	$	765	$	2,173	$	2,214
Loss recognized on sale	(2		)	3		(6		)	6		(2		)	3		(5		)	6		3		3		9		9		3		2		8		8
Cash flows
Cash proceeds from receivables sold	544			539		1,267			1,156		713			721		1,474			1,446		494		518		1,761		1,674		759		758		2,233		2,204
Collection fees received	1			1		1			1		1			1		1			1		—		—		1		1		—		—		1		1
Return received on retained interests	1			2		3			3		1			1		3			3		—		1		3		4		2		2		5		5

Cash flows from sales of receivables are reflected within Operating Activities on Duke Energy Ohio’s and Duke Energy Indiana’s Condensed Consolidated Statements of Cash Flows.

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

~~13.~~14. 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 unit’s vesting periods.

The following table presents Duke Energy’s basic and diluted EPS calculations and reconciles the weighted-average number of common shares outstanding to the diluted weighted-average number of common shares outstanding.

(In millions, except per-share amounts)

Income

Average
Shares

EPS
Three Months Ended June 30, 2014
Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted $ 611
707
$ 0.86
Three Months Ended June 30, 2013
Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted $ 340
706
$ 0.48



	Three Months Ended September 30,				Nine Months Ended September 30,
(in millions, except per share amounts)	2014		2013		2014		2013
Income from continuing operations attributable to Duke Energy common shareholders	$	887	$	942	$	2,351	$	1,884
Weighted-average shares outstanding - basic	707		706		707		706
Weighted-average shares outstanding - diluted	707		706		707		706
Earnings per share from continuing operations attributable to Duke Energy common shareholders
Basic	$	1.25	$	1.33	$	3.33	$	2.67
Diluted	$	1.25	$	1.33	$	3.33	$	2.67
Potentially dilutive items excluded from the calculation^(a)					2		2
Dividends declared per common share	$	0.795	$	0.78	$	2.355	$	2.31


(a)	Stock options and performance and unvested stock awards were not included in the dilutive securities calculation 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.

8891

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

(In millions, except per-share amounts)

Income

Average
Shares

EPS
Six Months Ended June 30, 2014
Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted $ 516
707
$ 0.73
Six Months Ended June 30, 2013
Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic $ 969
705
$ 1.37
Effect of dilutive securities:
Stock options, performance and restricted shares —
1

Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — diluted $ 969
706
$ 1.37

As of June 30, 2014 and 2013, 2 million 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 three months ended June 30, 2014 and 2013, Duke Energy declared dividends of $0.78 per share and $1.545 per share, respectively. For the six months ended June 30, 2014 and 2013, Duke Energy declared dividends of $1.56 per share and $2.31 per share, respectively.

~~14.~~15. STOCK-BASED COMPENSATION

For employee awards, equity classified stock-based compensation cost is measured at the service inception date or the grant date, based on the estimated achievement of certain performance metrics or the fair value of the award, and is recognized as expense or capitalized as a component of property, plant and equipment over the requisite service period.

Duke Energy recorded pretax stock-based compensation expense as follows.


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
(in millions)	2014		2013		2014		2013		2014		2013		2014		2013
Stock options	$	—	$	—	$	—	$	2	—		$	—	—		$	2
Restricted stock unit awards	11		12		22		26		8		10		30		36
Performance awards	5		7		10		18		4		7		14		25
Total	$	16	$	19	$	32	$	46	$	12	$	17	$	44	$	63
Tax benefit associated with stock-based compensation expense	$	6	$	8	$	12	$	18	$	5	$	6	17		$	24
Stock-based compensation costs capitalized	1		1		2		2		1		1		3		3

~~15.~~16. 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. 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-year 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. As of January 1, 2014, the qualified and non-qualified non-contributory defined benefit plans are closed to new and rehired non-union and certain unionized employees.

Duke Energy uses a December 31 measurement date for its defined benefit retirement plan assets and obligations.

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. Duke Energy made contributions directly to pension plan assets during the three and nine months ended September 30, 2013 of $27 million, all of which relates to Duke Energy Florida. Duke Energy did not make any contributions to its qualified defined benefit retirement plans during the ~~six~~nine months ended ~~June~~September 30, ~~2014 and 2013.~~2014.

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 8.9.

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

QUALIFIED PENSION PLANS

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

Three Months Ended June 30, 2014
(in millions) Duke Energy
Duke Energy Carolinas
Progress Energy
Duke Energy Progress
Duke Energy Florida
Duke Energy Ohio
Duke Energy Indiana
Service cost $ 34
$ 11
$ 10
$ 5
$ 5
$ 1
$ 2
Interest cost on projected benefit obligation 86
21
28
14
15
5
8
Expected return on plan assets (127 ) (33 ) (43 ) (22 ) (22 ) (6 ) (11 )
Amortization of actuarial loss 37
9
17
8
8
1
3
Amortization of prior service credit (3 ) (2 ) (1 ) (1 ) (1 ) —
—
Other 1
—
—
1
1
—
—
Net periodic pension costs $ 28
$ 6
$ 11
$ 5
$ 6
$ 1
$ 2

Three Months Ended June 30, 2013
(in millions) Duke Energy
Duke Energy Carolinas
Progress Energy
Duke Energy Progress
Duke Energy Florida
Duke Energy Ohio
Duke Energy Indiana
Service cost $ 42
$ 13
$ 15
$ 6
$ 7
$ 1
$ 3
Interest cost on projected benefit obligation 80
20
29
12
14
6
7
Expected return on plan assets (137 ) (37 ) (49 ) (24 ) (22 ) (7 ) (11 )
Amortization of actuarial loss 61
15
25
12
13
3
5
Amortization of prior service credit (3 ) (1 ) (1 ) —
(1 ) —
—
Other 1
—
—
—
—
—
—
Net periodic pension costs $ 44
$ 10
$ 19
$ 6
$ 11
$ 3
$ 4

Six Months Ended June 30, 2014
(in millions) Duke Energy
Duke Energy Carolinas
Progress Energy
Duke Energy Progress
Duke Energy Florida
Duke Energy Ohio
Duke Energy Indiana
Service cost $ 68
$ 21
$ 20
$ 10
$ 10
$ 2
$ 4
Interest cost on projected benefit obligation 172
42
56
27
29
10
15
Expected return on plan assets (255 ) (66 ) (86 ) (43 ) (43 ) (13 ) (20 )
Amortization of actuarial loss 74
18
34
16
16
2
6
Amortization of prior service credit (7 ) (4 ) (2 ) (1 ) (1 ) —
—
Other 3
1
1
1
1
—
—
Net periodic pension costs $ 55
$ 12
$ 23
$ 10
$ 12
$ 1
$ 5


	Six Months Ended June 30, 2013																					Three Months Ended September 30, 2014
(in millions)	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
Service cost	$	84		$	25		$	30		$	11		$	15		$	3		$	6		$	34		$	10		$	10		$	6		$	5		$	1		$	3
Interest cost on projected benefit obligation	160			40			58			25			27			11			14			86			22			28			13			14			5			7
Expected return on plan assets	(274		)	(74		)	(99		)	(47		)	(44		)	(15		)	(22		)	(128		)	(33		)	(44		)	(21		)	(21		)	(7		)	(10		)
Amortization of actuarial loss	122			30			50			23			25			6			11			37			8			17			8			8			1			3
Amortization of prior service credit	(6		)	(3		)	(2		)	—			(1		)	—			—			(4		)	(2		)	—			—			—			—			—
Other	3			1			1			—			—			—			—			3			1			1			—			—			—			—
Net periodic pension costs	$	89		$	19		$	38		$	12		$	22		$	5		$	9		$	28		$	6		$	12		$	6		$	6		$	—		$	3

9092

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)



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



	Nine Months Ended September 30, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana
Service cost	$	102		$	31		$	30		$	16		$	15		$	3		$	7
Interest cost on projected benefit obligation	258			64			84			40			43			15			22
Expected return on plan assets	(383		)	(99		)	(130		)	(64		)	(64		)	(20		)	(30		)
Amortization of actuarial loss	111			26			51			24			24			3			9
Amortization of prior service credit	(11		)	(6		)	(2		)	(1		)	(1		)	—			—
Other	6			2			2			1			1			—			—
Net periodic pension costs	$	83		$	18		$	35		$	16		$	18		$	1		$	8



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

NON-QUALIFIED PENSION PLANS

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


	Three Months Ended June 30, 2014										Three Months Ended September 30, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy		Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida
Service cost	$	1	$	—	$	1	$	—	$	—	$	1	$	—	$	—		$	1	$	—
Interest cost on projected benefit obligation	3		—		—		—		1		3		1		2			—		—
Amortization of actuarial loss	1		—		1		—		—		1		—		—			—		—
Amortization of prior service credit											—		—		(1		)	—		—
Net periodic pension costs	$	5	$	—	$	2	$	—	$	1	$	5	$	1	$	1		$	1	$	—

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)



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


	Three Months Ended June 30, 2013										Nine Months Ended September 30, 2014
(in millions)	Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy		Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida
Service cost	$	1	$	—	$	—	$	—	$	—	$	2	$	—	$	1		$	1	$	—
Interest cost on projected benefit obligation	3		1		2		1		1		10		1		4			1		1
Amortization of actuarial loss	1		—		1		—		—		2		—		1			—		—
Amortization of prior service credit											—		—		(1		)	—		—
Net periodic pension costs	$	5	$	1	$	3	$	1	$	1	$	14	$	1	$	5		$	2	$	1

Six Months Ended June 30, 2014
(in millions) Duke Energy
Duke Energy Carolinas
Progress Energy
Duke Energy Progress
Duke Energy Florida
Service cost $ 1
$ —
$ 1
$ —
$ —
Interest cost on projected benefit obligation 7
—
2
1
1
Amortization of actuarial loss 1
—
1
—
—
Amortization of prior service credit —
—
—
—
—
Net periodic pension costs $ 9
$ —
$ 4
$ 1
$ 1


	Six Months Ended June 30, 2013												Nine Months Ended September 30, 2013
(in millions)	Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida		Duke Energy			Duke Energy Carolinas		Progress Energy			Duke Energy Progress		Duke Energy Florida
Service cost	$	1		$	—	$	—		$	—	$	—	$	2		$	—	$	1		$	1	$	—
Interest cost on projected benefit obligation	7			1		4			1		1		10			1		5			1		1
Amortization of actuarial loss	3			—		2			—		—		4			—		3			1		1
Amortization of prior service credit	(1		)	—		(1		)	—		—		(1		)	—		(1		)	—		—
Net periodic pension costs	$	10		$	1	$	5		$	1	$	1	$	15		$	1	$	8		$	3	$	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 uses a December 31 measurement date for its other post-retirement benefit plan assets and obligations. However, due to the impact of certain changes in Legacy Progress Energy health care benefits announced in September 2013, Duke Energy remeasured its Legacy Progress Energy other post-retirement benefit plan obligation as of September 30, 2013. There are no plan assets associated with the Legacy Progress Energy other post-retirement benefit plan. The discount rate used for the remeasurement was 4.7%. The health care cost trend rate of 8.5% reduces to 5.0% over eight years. The mortality tables were updated to account for mortality improvement.

Duke Energy did not make any contributions to its other post-retirement benefit plans during the three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013.

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



	Three Months Ended September 30, 2014
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Indiana
Service cost	$	2		$	—		$	1		$	—		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	13			3			6			3			3			1
Expected return on plan assets	(3		)	(2		)	—			—			—			—
Amortization of actuarial loss	9			1			10			8			3			—
Amortization of prior service credit	(31		)	(3		)	(24		)	(19		)	(5		)	—
Net periodic other post-retirement benefit costs	$	(10	)	$	(1	)	$	(7	)	$	(8	)	$	1		$	1

9194

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

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


	Three Months Ended June 30, 2014																					Three Months Ended September 30, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana			Duke Energy			Duke Energy Carolinas			Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Indiana
Service cost	$	3		$	1		$	1		$	1		$	1		$	—		$	—		$	7		$	1		$	6	$	3	$	2	$	1
Interest cost on accumulated post-retirement benefit obligation	13			3			5			2			3			1			2			19			3			12		7		5		1
Expected return on plan assets	(3		)	(2		)	—			—			—			—			(1		)	(4		)	(2		)	—		—		—		(1		)
Amortization of actuarial loss (gain)	10			—			11			8			3			(1		)	—
Amortization of actuarial loss																						13			—			13		8		4		1
Amortization of prior service credit	(32		)	(2		)	(23		)	(18		)	(6		)	—			—			(3		)	(2		)	—		—		—		—
Net periodic other post-retirement benefit costs	$	(9	)	$	—		$	(6	)	$	(7	)	$	1		$	—		$	1		$	32		$	—		$	31	$	18	$	11	$	2


	Three Months Ended June 30, 2013																			Nine Months Ended September 30, 2014
(in millions)	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
Service cost	$	7		$	—		$	5		$	3		$	2	$	—		$	—	$	7		$	1		$	3		$	1		$	2		$	—		$	—
Interest cost on accumulated post-retirement benefit obligation	18			3			12			6			4		1			2		38			9			17			8			9			1			4
Expected return on plan assets	(4		)	(2		)	—			—			—		—			—		(9		)	(6		)	—			—			—			—			(1		)
Amortization of actuarial loss (gain)	13			1			15			9			4		(1		)	—		29			2			31			23			8			(1		)	—
Amortization of prior service credit	(3		)	(2		)	(1		)	(1		)	—		—			—		(94		)	(8		)	(71		)	(55		)	(16		)	—			—
Net periodic other post-retirement benefit costs	$	31		$	—		$	31		$	17		$	10	$	—		$	2	$	(29	)	$	(2	)	$	(20	)	$	(23	)	$	3		$	—		$	3


	Six Months Ended June 30, 2014																					Nine Months Ended September 30, 2013
(in millions)	Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana			Duke Energy			Duke Energy Carolinas			Progress Energy			Duke Energy Progress			Duke Energy Florida		Duke Energy Ohio			Duke Energy Indiana
Service cost	$	5		$	1		$	2		$	1		$	2		$	—		$	—		$	21		$	2		$	17		$	9		$	6	$	—		$	1
Interest cost on accumulated post-retirement benefit obligation	25			6			11			5			6			1			3			55			9			35			19			13		1			4
Expected return on plan assets	(6		)	(4		)	—			—			—			—			(1		)	(11		)	(7		)	—			—			—		—			(1		)
Amortization of actuarial loss (gain)	20			1			21			15			5			(1		)	—			39			2			42			26			12		(1		)	1
Amortization of prior service credit	(63		)	(5		)	(47		)	(36		)	(11		)	—			—			(9		)	(6		)	(1		)	(1		)	—		—			—
Net periodic other post-retirement benefit costs	$	(19	)	$	(1	)	$	(13	)	$	(15	)	$	2		$	—		$	2		$	95		$	—		$	93		$	53		$	31	$	—		$	5

Six Months Ended June 30, 2013
(in millions) Duke Energy
Duke Energy Carolinas
Progress Energy
Duke Energy Progress
Duke Energy Florida
Duke Energy Ohio
Duke Energy Indiana
Service cost $ 14
$ 1
$ 11
$ 6
$ 4
$ —
$ —
Interest cost on accumulated post-retirement benefit obligation 36
6
23
12
8
1
3
Expected return on plan assets (7 ) (5 ) —
—
—
—
—
Amortization of actuarial loss (gain) 26
2
29
18
8
(1 ) —
Amortization of prior service credit (6 ) (4 ) (1 ) (1 ) —
—
—
Net periodic other post-retirement benefit costs $ 63
$ —
$ 62
$ 35
$ 20
$ —
$ 3

~~PART I~~

~~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.~~

~~Combined Notes to Condensed Consolidated Financial Statements – (Continued)~~

~~(Unaudited)~~

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.

As of January 1, 2014, for new and rehired non-union and certain unionized employees who are not eligible to participate in Duke Energy’s defined benefit plans, an additional employer contribution of 4 percent of eligible pay per pay period is provided to the employee’s savings plan account, which is subject to a three-year vesting schedule.

PART I

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.

Combined Notes to Condensed Consolidated Financial Statements – (Continued)

(Unaudited)

The following table includes pretax employer matching contributions ~~as well as the additional contribution of 4 percent of eligible pay per pay period for employees not eligible to participate in a defined benefit plan,~~ 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		Duke Energy		Duke Energy Carolinas		Progress Energy		Duke Energy Progress		Duke Energy Florida		Duke Energy Ohio		Duke Energy Indiana
Three Months Ended June 30,
Three Months Ended September 30,															Three Months Ended September 30,
2014(a)	$	36	$	12	$	11	$	7	$	3	$	1	$	2	$	30	$	10	$	10	$	7	$	3	$	—	$	1
2013	30		10		10		6		3		1		1		30		10		12		7		4		—		2
Six Months Ended June 30,
Nine Months Ended September 30,															Nine Months Ended September 30,
2014(a)	$	80	$	26	$	23	$	16	$	7	$	2	$	4	$	110	$	36	$	33	$	23	$	10	$	2	$	5
2013	71		24		22		12		7		2		3		101		34		34		19		11		2		5


(a)	For the three and nine months ended September 30, 2014, amounts include the additional contribution of 4 percent of eligible pay per pay period for employees not eligible to participate in a defined benefit plan.

~~16.~~17. INCOME TAXES

The effective tax rates from continuing operations for each of the Duke Energy Registrants are included in the following table.


	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014		2013		2014		2013		2014		2013
Duke Energy	25.4	%	32.5	%	13.6	%	33.6	%	34.0	%	30.9	%	31.4	%	32.3	%
Duke Energy Carolinas	28.9	%	37.4	%	33.6	%	37.2	%	33.9	%	37.9	%	33.7	%	37.5	%
Progress Energy	37.7	%	59.9	%	37.4	%	36.7	%	37.1	%	38.8	%	37.3	%	38.1	%
Duke Energy Progress	37.3	%	39.6	%	36.9	%	38.7	%	36.3	%	35.7	%	36.6	%	37.3	%
Duke Energy Florida	38.7	%	38.0	%	38.6	%	39.8	%	38.5	%	40.0	%	38.6	%	40.0	%
Duke Energy Ohio	36.2	%	36.3	%	35.5	%	35.9	%	38.3	%	35.9	%	34.9	%	36.5	%
Duke Energy Indiana	36.9	%	37.5	%	36.8	%	37.5	%	31.6	%	36.6	%	35.2	%	37.2	%

The ~~decrease~~increase in the effective tax rate for Duke Energy for the three ~~and six~~ months ended ~~June~~September 30, 2014 is primarily due to a favorable deferred state tax adjustment in the ~~first~~third quarter of ~~2014 impairment of the Midwest Generation business and a deferred tax benefit recorded in the second quarter of 2014 as a result of the merger of two Chilean subsidiaries.~~2013.

The decrease in the effective tax rate for Duke Energy Carolinas for the three ~~and six~~ months ended ~~June~~September 30, 2014 is primarily due to an increase in the tax benefit related to the manufacturing deduction in 2014 as the prior year deduction was limited by taxable income. The decrease in the effective tax rate for Duke Energy Carolinas for the nine months ended September 30, 2014 is primarily due to favorable audit settlements, ~~and~~ changes in apportionment related to state income ~~tax.~~tax, and the tax benefit related to the manufacturing deduction in 2014 as the prior year deduction was limited by taxable income.

The decrease in the effective tax rate for Progress Energy for the three months ended ~~June 30, 2014 is primarily due to the pretax loss in 2013 related to the 2013 FPSC settlement agreement.~~

~~The decrease in the effective tax rate for Duke Energy Progress for the three and six months ended June~~September 30, 2014 is primarily due to certain nondeductible book depreciation.

The decrease in the effective tax rate for Duke Energy Florida for the ~~six~~three and nine months ended ~~June~~September 30, 2014 is primarily due to certain nondeductible book depreciation.

The increase in the effective tax rate for Duke Energy Ohio for the three months ended September 30, 2014 is primarily due to an increase in the tax benefit related to the manufacturing deduction. The decrease in the effective tax rate for Duke Energy Ohio for the nine months ended September 30, 2014 is primarily due to certain nondeductible book depreciation.

The decrease in the effective tax rate for Duke Energy Indiana for the three and nine months ended September 30, 2014 is primarily due to a reduction in the statutory Indiana corporate income tax rate and a prior period audit settlement.

~~17.~~18. SUBSEQUENT EVENTS

For information on subsequent events related to acquisitions and dispositions, regulatory matters, commitments and contingencies, and debt and credit facilities see Notes 2, 4, 5, and 6, respectively.

9396

PART I

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Duke Energy Corporation (collectively with its subsidiaries, Duke Energy) and 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) (collectively referred to as the Subsidiary Registrants). However, none of the registrants makes any representation as to information related solely to Duke Energy or the Subsidiary Registrants of Duke Energy other than itself.

DUKE ENERGY

Duke Energy is an energy company headquartered in Charlotte, North Carolina. Duke Energy operates in the United States (U.S.) through its wholly owned subsidiaries Duke Energy Carolinas, Duke Energy Progress, Duke Energy Florida, Duke Energy Ohio, and Duke Energy Indiana, as well as in Latin America through International Energy.

When discussing Duke Energy’s consolidated financial information, it necessarily includes the results of the Subsidiary Registrants, which, along with Duke Energy, are collectively referred to as the Duke Energy Registrants.

Management’s Discussion and Analysis includes financial information prepared in accordance with generally accepted accounting principles (GAAP) in the U.S., as well as certain non-GAAP financial measures such as adjusted earnings, adjusted diluted earnings per share (EPS), and adjusted segment income, discussed below. Generally, a non-GAAP financial measure is a numerical measure of financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP. The non-GAAP financial measures should be viewed as a supplement to, and not a substitute for, financial measures presented in accordance with GAAP. Non-GAAP measures presented herein may not be comparable to similarly titled measures used by other companies.

Management’s Discussion and Analysis should be read in conjunction with the Condensed Consolidated Financial Statements and Notes for the ~~six~~nine months ended ~~June~~September 30, 2014, and with Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013.

Midwest Generation Exit

On August 21, 2014, Duke Energy Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a purchase and sale agreement (PSA) with a subsidiary of Dynegy Inc. (Dynegy) whereby Dynegy will acquire Duke Energy Ohio's nonregulated Midwest generation business (Disposal Group). The results of operations of the nonregulated Midwest generation business have been classified as Discontinued Operations on the Condensed Consolidated Statements of Operations for the current and prior periods presented. Closing is expected to be completed in the fourth quarter of 2014 or the first quarter of 2015. See Note 2 to the Condensed Consolidated Financial Statements, “Acquisitions and Dispositions,” for further discussion of the Disposal Group.

Results of Operations

In this section, Duke Energy provides analysis and discussion of earnings and factors affecting earnings on both a GAAP and non-GAAP basis.

Management evaluates financial performance in part based on the non-GAAP financial measures, adjusted earnings and adjusted diluted EPS. These items are measured as income from continuing operations ~~after deducting~~net of income (loss) attributable to noncontrolling interests, adjusted for the dollar and ~~per-share~~per share impact of ~~special items and~~ mark-to-market impacts of economic hedges in the Commercial Power ~~segment.~~segment and special items including the operating results of the Disposal Group classified as discontinued operations for GAAP purposes. Special items represent certain charges and credits, which management believes will not be recurring on a regular basis, although it is reasonably possible such charges and credits could recur. ~~Mark-to-market~~As result of the agreement in August of 2014 to sell the Disposal Group to Dynegy, the operating results of the Disposal Group were classified as discontinued operations in the current period and retrospectively, including a portion of the mark-to-market adjustments ~~reflect~~associated with derivative contracts. Management believes that including the ~~impact~~operating results of ~~derivative~~the Disposal Group classified as discontinued operations better reflects its financial performance and therefore has included these results in adjusted earnings and adjusted diluted EPS. Derivative contracts ~~which~~ are used in Duke Energy’s hedging of a portion of the economic value of its generation assets in the Commercial Power ~~segment and also relate to existing derivative positions that may have tenors beyond the planned disposal date of the nonregulated Midwest generation business.~~segment. The mark-to-market impact of derivative contracts is recognized in GAAP earnings immediately and, if associated with the Disposal Group, classified as discontinued operations, as such derivative contracts do not qualify for hedge accounting or regulatory treatment. The economic value of generation assets is subject to fluctuations in fair value due to market price volatility of input and output commodities (e.g., coal, electricity, natural gas). Economic hedging involves both purchases and sales of those input and output commodities related to generation assets. Operations of the generation assets are accounted for under the accrual method. Management believes excluding impacts of mark-to-market changes of the derivative contracts from adjusted earnings until settlement better matches the financial impacts of the derivative contract with the portion of economic value of the underlying hedged asset. However, due to the divestiture of the ~~nonregulated Midwest generation business~~Disposal Group as mentioned above, certain derivative positions have tenors beyond the planned disposal date of these assets. As such, management ~~expects to exclude~~excluded any settlement of these derivative positions from adjusted diluted EPS as these realized gains and losses more closely relate to the ~~loss on~~ disposal of these assets. Management believes the presentation of adjusted earnings and adjusted diluted EPS provides useful information to investors, as it provides them an additional relevant comparison of Duke Energy’s performance across periods. Management uses these non-GAAP financial measures for planning and forecasting and for reporting results to the Board of Directors, employees, shareholders, analysts and investors concerning Duke Energy’s financial performance. Adjusted diluted EPS is also used as a basis for employee incentive bonuses. The most directly comparable GAAP measures for adjusted earnings and adjusted diluted EPS are Net Income Attributable to Duke Energy Corporation and Diluted EPS Attributable to Duke Energy Corporation common shareholders, which include the dollar and ~~per-share~~per share impact of special items, mark-to-market impacts of economic hedges in the Commercial Power segment and discontinued operations.

PART I

Management evaluates segment performance based on segment income. Segment income is defined as income from continuing operations net of income (loss) attributable to noncontrolling interests. Segment income, as discussed below, includes intercompany revenues and expenses that are eliminated in the Condensed Consolidated Financial Statements. Management also uses adjusted segment income as a measure of historical and anticipated future segment performance. Adjusted segment income is a non-GAAP financial measure, as it is based upon segment income adjusted for ~~special items and~~the mark-to-market impacts of economic hedges in the Commercial Power ~~segment.~~segment and special items, including the operating results of the Disposal Group classified as discontinued operations for GAAP purposes. Management believes the presentation of adjusted segment income as presented provides useful information to investors, as it provides them with an additional relevant comparison of a segment’s performance across periods. The most directly comparable GAAP measure for adjusted segment income is segment income, which represents segment income from continuing operations, including any special items and the mark-to-market impacts of economic hedges in the Commercial Power segment.

Duke Energy’s adjusted earnings, adjusted diluted EPS, segment income and adjusted segment income may not be comparable to similarly titled measures of another company because other entities may not calculate the measures in the same manner.

See Note 3 to the Condensed Consolidated Financial Statements, “Business Segments,” for a discussion of Duke Energy’s segment structure.

~~PART I~~

Executive Overview

The following table reconciles non-GAAP measures to their most directly comparable GAAP measures.

Three Months Ended June 30, 2014
(in millions, except per-share amounts)
Regulated
Utilities

International
Energy

Commercial
Power

Total Reportable
Segments

Other

Duke
Energy

Per
Diluted
Share

Adjusted segment income/Adjusted earnings $ 689
$ 146
$ 16
$ 851
$ (65 ) $ 786
$ 1.11
Costs to achieve Progress Energy merger —
—
—
—
(38 ) (38 ) (0.06 )
Economic hedges (mark-to-market) —
—
(136 ) (136 ) —
(136 ) (0.19 )
Segment income (loss) $ 689
$ 146
$ (120 ) $ 715
$ (103 ) 612

Loss from Discontinued Operations (3 ) —
Net Income Attributable to Duke Energy $ 609
$ 0.86



	Three Months Ended September 30, 2014
(in millions, except per-share amounts)	Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations		Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	920	$	80	$	51		$	1,051		$	(58	)	$	—	$	993		$	1.40
Costs to achieve Progress Energy merger	—		—		—			—			(35		)	—		(35		)	(0.05		)
Midwest generation operations	—		—		(68		)	(68		)	(8		)	76		—			—
Asset sales	—		—		—			—			9			—		9			0.01
Discontinued operations	—		—		—			—			—			307		307			0.44
Segment income (loss)/ Net Income Attributable to Duke Energy Corporation	$	920	$	80	$	(17	)	$	983		$	(92	)	$	383	$	1,274		$	1.80

Three Months Ended June 30, 2013
(in millions, except per-share amounts)
Regulated
Utilities

International
Energy

Commercial
Power

Total Reportable
Segments

Other
Duke Energy

Per
Diluted
Share

Adjusted segment income (loss) /Adjusted earnings $ 590
$ 87
$ (3 ) $ 674
$ (57 ) $ 617
$ 0.87
Crystal River Unit 3 impairment (180 ) —
—
(180 ) —
(180 ) (0.26 )
Nuclear development charges (57 ) —
—
(57 ) —
(57 ) (0.08 )
Costs to achieve Progress Energy merger —
—
—
—
(51 ) (51 ) (0.07 )
Litigation reserve —
—
—
—
(31 ) (31 ) (0.04 )
Economic hedges (mark-to-market) —
—
44
44
—
44
0.06
Segment income $ 353
$ 87
$ 41
$ 481
$ (139 ) 342

Loss from Discontinued Operations (3 ) —
Net Income Attributable to Duke Energy $ 339
$ 0.48



	Three Months Ended September 30, 2013
(in millions, except per-share amounts)	Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations		Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	923	$	116	$	15		$	1,054		$	(21	)	$	—	$	1,033		$	1.46
Costs to achieve Progress Energy merger	—		—		—			—			(54		)	—		(54		)	(0.08		)
Midwest generation operations	—		—		(43		)	(43		)	11			32		—			—
Discontinued operations	—		—		—			—			—			25		25			0.04
Segment income (loss)/ Net Income Attributable to Duke Energy Corporation	$	923	$	116	$	(28	)	$	1,011		$	(64	)	$	57	$	1,004		$	1.42

The variance in adjusted earnings for three months ended ~~June~~September 30, 2014, compared to the same period in 2013, was primarily due to:

Higher depreciation and amortization expense primarily due to higher depreciable asset base and lower reductions to cost of removal reserves;

Lower earnings in Latin America, due to higher purchased power costs in Brazil and an unplanned outage in Chile;

Lower post in-service debt returns due to projects added to customer rates;

Lower weather-normalized retail customer volumes; and

A higher effective tax rate.

Partially offset by:

Increased retail pricing and riders primarily resulting from the implementation of revised rates in most jurisdictions;

Higher PJM Interconnection, LLC (PJM) capacity revenues; and

Favorable weather driven by less mild summer temperatures than in the prior year.

PART I



	Nine Months Ended September 30, 2014
(in millions, except per-share amounts)	Regulated Utilities		International Energy		Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations			Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	2,346	$	356	$	77		$	2,779		$	(171	)	$	—		$	2,608		$	3.69
Costs to achieve Progress Energy merger	—		—		—			—			(107		)	—			(107		)	(0.15		)
Midwest generation operations	—		—		(82		)	(82		)	—			82			—			—
Asset sales	—		—		—			—			9			—			9			0.01
Asset impairment	—		—		(59		)	(59		)	—			—			(59		)	(0.08		)
Economic hedges (mark-to-market)	—		—		(6		)	(6		)	—			—			(6		)	(0.01		)
Discontinued operations	—		—		—			—			—			(659		)	(659		)	(0.94		)
Segment income (loss)/ Net Income Attributable to Duke Energy Corporation	$	2,346	$	356	$	(70	)	$	2,632		$	(269	)	$	(577	)	$	1,786		$	2.52



	Nine Months Ended September 30, 2013
(in millions, except per-share amounts)	Regulated Utilities			International Energy		Commercial Power			Total Reportable Segments			Other			Eliminations/ Discontinued Operations		Duke Energy			Per Diluted Share
Adjusted segment income/Adjusted earnings	$	2,169		$	300	$	18		$	2,487		$	(114	)	$	—	$	2,373		$	3.36
Costs to achieve Progress Energy merger	—			—		—			—			(139		)	—		(139		)	(0.20		)
Nuclear development charges	(57		)	—		—			(57		)	—			—		(57		)	(0.08		)
Litigation reserve	—			—		—			—			(31		)	—		(31		)	(0.04		)
Crystal River Unit 3 impairment	(180		)	—		—			(180		)	—			—		(180		)	(0.26		)
Midwest generation operations	—			—		(72		)	(72		)	6			66		—			—
Discontinued operations	—			—		—			—			—			11		11			0.01
Segment income (loss)/ Net Income Attributable to Duke Energy Corporation	$	1,932		$	300	$	(54	)	$	2,178		$	(278	)	$	77	$	1,977		$	2.79

The variance in adjusted earnings for nine months ended September 30, 2014, compared to the same period in 2013, was primarily due to:

Increased retail pricing and riders primarily resulting from the implementation of revised rates in most jurisdictions;

Favorable weather in 2014 compared to 2013;

Higher results at Commercial Power due to ceasing depreciation on assets held for sale and higher PJM capacity revenues;

Higher results in Latin America due to a tax benefit related to the reorganization of Chilean operations;

~~A decrease in the effective tax rates due to a state tax settlement that resulted in a favorable adjustment to deferred taxes;~~ and

~~Lower operating~~Higher net wholesale margins resulting from growth in contracted amounts and ~~maintenance expense primarily due to decreased donations required by a 2013 NCUC rate case order and nuclear levelization.~~favorable weather.

Partially offset by:

Higher depreciation and amortization expense primarily due to higher depreciable asset base and lower reductions to cost of removal ~~reserves.~~

Six Months Ended June 30, 2014
(in millions, except per-share amounts)
Regulated
Utilities

International
Energy

Commercial
Power

Total Reportable
Segments

Other

Duke
Energy

Per
Diluted
Share

Adjusted segment income/Adjusted earnings $ 1,426
$ 276
$ 26
$ 1,728
$ (113 ) $ 1,615
$ 2.28
Midwest Generation impairment —
—
(867 ) (867 ) —
(867 ) (1.23 )
Costs to achieve Progress Energy merger —
—
—
—
(72 ) (72 ) (0.10 )
Economic hedges (mark-to-market) —
—
(158 ) (158 ) —
(158 ) (0.22 )
Segment income (loss) $ 1,426

$ 276

$ (999 )
$ 703

$ (185 )
$ 518

Loss from Discontinued Operations (6 ) (0.01 )
Net Income Attributable to Duke Energy $ 512
$ 0.72

~~PART I~~

Six Months Ended June 30, 2013
(in millions, except per-share amounts)
Regulated
Utilities

International
Energy

Commercial
Power

Total Reportable
Segments

Other
Duke Energy

Per
Diluted
Share

Adjusted segment income/Adjusted earnings $ 1,246
$ 184
$ 3
$ 1,433
$ (100 ) $ 1,333
$ 1.89
Crystal River Unit 3 impairment (180 ) —
—
(180 ) —
(180 ) (0.26 )
Costs to achieve Progress Energy merger —
—
—
—
(85 ) (85 ) (0.13 )
Nuclear development charges (57 ) —
—
(57 ) —
(57 ) (0.08 )
Litigation reserve —
—
—
—
(31 ) (31 ) (0.04 )
Economic hedges (mark-to-market) —
—
(4 ) (4 ) —
(4 ) (0.01 )
Segment income (loss) $ 1,009
$ 184
$ (1 ) $ 1,192
$ (216 ) 976

Loss from Discontinued Operations (3 ) —
Net Income Attributable to Duke Energy $ 973
$ 1.37

~~The variance in adjusted earnings for six months ended June 30, 2014, compared to the same period in 2013, was primarily due to:~~

~~Increased retail pricing and riders primarily resulting from the implementation of revised rates in most jurisdictions;~~

~~Favorable weather in 2014 compared to 2013;~~

~~Higher results in Latin America due to a tax benefit related to the reorganization of Chilean operations and higher spot pricing and volumes in Brazil;~~

~~Increased weather-normal retail sales volumes for the regulated businesses;~~

~~A decrease in the effective tax rates due to a state tax settlement that resulted in a favorable adjustment to deferred taxes; and~~

~~Higher results from the wind and solar portfolios.~~

~~Partially offset by:~~

~~Higher depreciation and amortization expense primarily due to higher depreciable asset base and a lower reduction to cost of removal reserve;~~reserves;

Lower post in-service debt returns due to projects added to customer rates.

PART I

SEGMENT RESULTS

The remaining information in this discussion of results of operations is presented on a GAAP basis.

Regulated Utilities


	Three Months Ended June 30,							Six Months Ended June 30,							Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)	2014		2013		Variance			2014		2013		Variance			2014		2013		Variance			2014		2013		Variance
Operating Revenues	$	5,283	$	4,920	$	363		$	11,088	$	9,980	$	1,108		$	5,986	$	5,786	$	200		$	17,074	$	15,766	$	1,308
Operating Expenses	4,019		4,165		(146		)	8,446		8,005		441			4,361		4,131		230			12,807		12,136		671
Gains on Sales of Other Assets and Other, net	—		4		(4		)	1		6		(5		)	1		—		1			2		6		(4		)
Operating Income	1,264		759		505			2,643		1,981		662			1,626		1,655		(29		)	4,269		3,636		633
Other Income and Expenses, net	62		48		14			131		109		22			75		57		18			206		166		40
Interest Expense	275		242		33			545		478		67			271		235		36			816		713		103
Income Before Income Taxes	1,051		565		486			2,229		1,612		617			1,430		1,477		(47		)	3,659		3,089		570
Income Tax Expense	362		212		150			803		603		200			510		554		(44		)	1,313		1,157		156
Segment Income	$	689	$	353	$	336		$	1,426	$	1,009	$	417		$	920	$	923	$	(3	)	$	2,346	$	1,932	$	414

Duke Energy Carolinas GWh sales	20,836		20,202		634			44,529		42,448		2,081			22,821		22,935		(114		)	67,350		65,383		1,967
Duke Energy Progress GWh sales	14,693		14,055		638			30,854		28,756		2,098			16,540		17,005		(465		)	47,394		45,761		1,633
Duke Energy Florida GWh sales	9,840		9,853		(13		)	18,501		17,869		632			11,550		11,263		287			30,051		29,132		919
Duke Energy Ohio GWh sales	5,824		5,800		24			12,303		11,978		325			6,465		6,589		(124		)	18,768		18,567		201
Duke Energy Indiana GWh sales	8,455		7,937		518			17,329		16,442		887			8,224		8,747		(523		)	25,553		25,189		364
Total Regulated Utilities GWh sales	59,648		57,847		1,801			123,516		117,493		6,023			65,600		66,539		(939		)	189,116		184,032		5,084
Net proportional MW capacity in operation								49,452		49,560		(108		)								49,471		49,425		46

~~PART I~~

Three Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Regulated Utilities’ results were ~~positively impacted~~essentially flat as a result of higher depreciation and amortization expense, higher operation and maintenance costs, higher interest expense, and lower weather-normal sales volumes. These impacts were offset by higher retail pricing, and ~~rate riders,~~ favorable weather, lower operation and maintenance costs, an increase in wholesale power margins, and prior year impairments. These impacts were partially offset by higher depreciation and amortization expense and higher interest expense.weather. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variancewas driven primarily by:

A ~~$142~~$148 millionnet increase in retail pricing primarily due to retail rate ~~changes and updated rate riders;~~changes;

A ~~$138~~$118 million increase in fuel revenues driven primarily by ~~(i) increased demand from electric retail customers resulting from favorable weather conditions, and (ii)~~ higher fuel rates for electric retail customers for all jurisdictions, except North ~~Carolina.~~Carolina; partially offset by decreased demand from electric retail customers. Fuel revenues represent sales to retail and wholesale customers; and

A ~~$73~~$36 million increase in electric sales (net of fuel revenue) to retail customers due to ~~more~~ favorable weather conditions. For the Carolinas, cooling degree days for the ~~second~~third quarter of 2014 were 1011 percent ~~above~~below normal as compared with 1417 percent below normal during the same period in 2013. For the Midwest, cooling degree days for the ~~second~~third quarter of 2014 were ~~flat to~~29 percent below normal as compared with 111 percent below normal during the same period in 2013. For Florida, cooling degree days for the ~~second~~third quarter of 2014 were 1 percent ~~above~~below normal as compared with 14 percent below normal during the same period in ~~2013;~~2013.

Partially offset by:

A $76 million decrease in gross receipts tax revenue due to the North Carolina Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014; and

~~An $18~~A $29 million ~~increase~~decrease in ~~wholesale power revenues, net~~weather-normal sales volumes to retail customers (net of ~~sharing, primarily due to additional volumes and capacity charges for customers served under long-term contracts.~~fuel revenue) reflecting decreased demand.

Operating Expenses. The variance was driven primarily by:

A $345 million decrease due to 2013 impairment and other charges primarily related to Crystal River Unit 3 Nuclear Station (Crystal River Unit 3) and Duke Energy Florida's proposed Levy Nuclear Station (Levy);

~~A $22 million decrease due to a 2013 impairment resulting from the decision to suspend the application for two proposed nuclear units at the Shearon Harris Nuclear Station (Harris); and~~

~~A $20 million decrease in operating and maintenance expense primarily due to 2013 donations for low-income customers and job training in accordance with a 2013 NCUC rate case order.~~

~~Partially offset by:~~

~~A $134~~$118 million increase in fuel expense (including purchased power and natural gas purchases for resale) primarily related to (i) ~~higher volumes~~the application of ~~coal and gas used~~the Nuclear Insurance Insurance Limited (NEIL) proceeds in ~~electric generation due primarily to increased generation resulting from favorable weather conditions,~~2013 for Duke Energy Florida and (ii) higher natural gas prices; ~~and~~

A $131 million increase in depreciation and amortization expense primarily due to increases in depreciation as a result of additional plant in service and amortization of regulatory assets, and higher 2013 reductions to cost of removal reserves in accordance with regulatory orders.

~~Other Income and Expenses, net.~~ ~~The variance is primarily due to recognition of post in-service equity returns for projects that had been completed prior to being reflected in customer rates.~~

~~Interest Expense.~~ ~~The variance was primarily due to no longer recording post in-service debt returns on projects now reflected in customer rates.~~

~~Income Tax Expense.~~ The variance was primarily due to an increase in pretax income. The effective tax rate for the three months ended June 30, 2014 and 2013 was 34.4 percent and 37.6 percent, respectively. The decrease in the effective tax rate is primarily due to favorable audit settlements and changes in apportionment related to state income tax.

~~Six Months Ended June 30, 2014 as Compared to June 30, 2013~~

Regulated Utilities’ results were positively impacted by higher retail pricing and rate riders, favorable weather, higher weather normal sales volumes, an increase in wholesale power margins, and prior year impairments. These impacts were partially offset by ~~higher depreciation and amortization expense, higher operation and maintenance costs, and higher interest expense. The following is a detailed discussion of the variance drivers by line item.~~

~~PART I~~

~~Operating Revenues.~~ ~~The variance was driven primarily by:~~

~~A $467 million increase in fuel revenues driven primarily by~~ (i) increased demand from electric retail customers resulting from favorable weather conditions, and (ii) higher fuel rates for electric retail customers for all jurisdictions, except North Carolina. Fuel revenues represent sales to retail and wholesale customers;

~~A $357 million net increase in retail pricing primarily due to retail rate changes and updated rate riders;~~

A $168 million increase in electric sales (net of fuel revenue) to retail customers due to more favorable weather conditions. For the first half of 2014 in the Carolinas, cooling degree days were 8 percent above normal as compared with 15 percent below normal during the same period in 2013, and heating degree days were 15 percent above normal as compared with 7 percent above normal during the same period in 2013. For the first half of 2014 in the Midwest, heating degree days were 22 percent above normal as compared with 5 percent above normal during the same period in 2013. For the first half of 2014 in Florida, heating degree days were 1 percent above normal as compared with 19 percent below normal during the same period in 2013;

~~A $64 million increase in weather-normal sales volumes to retail customers (net of fuel revenue) reflecting increased demand; and~~

~~A $49 million increase in wholesale power revenues, net of sharing, primarily due to additional volumes and capacity charges for customers served under long-term contracts.~~

~~Operating Expenses.~~ ~~The variance was driven primarily by:~~

~~A $454 million increase in fuel expense (including purchased power and natural gas purchases for resale) primarily related to (i) higher~~lower volumes of coal, oil and gas used in electric generation, ~~due primarily to increased generation resulting from favorable weather conditions,~~ and (ii) ~~higher natural gas~~lower coal prices;

A ~~$274~~$113 million increase in depreciation and amortization expense primarily due to increases in depreciation as a result of additional plant in service and amortization of regulatory assets, and higher 2013 reductions to cost of removal reserves in accordance with regulatory orders; and

~~An $83~~

A $41 million increase in operating and maintenance expense primarily due to higher nuclear costs, including nuclear outage levelization costs and higher environmental and operational costs that are recoverable in rates; partially offset by decreased benefits costsand 2013 donations in accordance with 2013 North Carolina Utilities Commission (NCUC) and Public Service Commission of South Carolina (PSCSC) rate case orders.

100

PART I

Partially offset by:

A $41 million decrease in property and other taxes primarily due to the termination of the collection of the North Carolina gross receipts tax as mentioned above, partially offset by higher property taxes.

Other Income and Expenses, net. The varianceis primarily due to recognition of post in-service equity returns for projects that had been completed prior to being reflected in customer rates.

Interest Expense. The variancewas primarily due to no longer recording post in-service debt returns on projects now reflected in customer rates.

Income Tax Expense. The variance was primarily due to a decrease in pretax income. The effective tax rate for the three months ended September 30, 2014 and 2013 was 35.7 percent and 37.5 percent, respectively. The decrease in the effective tax rate is primarily due to the tax benefit related to the manufacturing deduction in 2014 as the prior year deduction was limited by taxable income.

Nine Months Ended September 30, 2014 as Compared to September 30, 2013

Regulated Utilities’ results were positively impacted by higher retail pricing and rate riders, favorable weather, an increase in wholesale power margins, higher weather-normal sales volumes, and prior year impairments. These impacts were partially offset by higher depreciation and amortization expense, higher operation and maintenance costs, and higher interest expense. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variancewas driven primarily by:

A $580 million increase in fuel revenues driven primarily by increased demand from electric retail customers resulting from favorable weather conditions, and higher fuel rates for electric retail customers for all jurisdictions, except North Carolina. Fuel revenues represent sales to retail and wholesale customers;

A $508 million net increase in retail pricing primarily due to retail rate changes and updated rate riders;

A $203 million increase in electric sales (net of fuel revenue) to retail customers due to more favorable weather conditions. For the first nine months of 2014 in the Carolinas, cooling degree days were 5 percent below normal as compared with 16 percent below normal during the same period in 2013, and heating degree days were 15 percent above normal as compared with 7 percent above normal during the same period in 2013. For the first nine months of 2014 in the Midwest, cooling degree days were 21 percent below normal as compared with 8 percent below normal during the same period in 2013, and heating degree days were 23 percent above normal as compared with 5 percent above normal during the same period in 2013. For the first nine months of 2014 in Florida, cooling degree days were 1 percent below normal as compared with 2 percent below normal during the same period in 2013, and heating degree days were 1 percent above normal as compared with 22 percent below normal during the same period in 2013;

A $51 million increase in wholesale power revenues, net of sharing, primarily due to additional volumes and capacity charges for customers served under long-term contracts; and

A $35 million increase in weather-normal sales volumes to retail customers (net of fuel revenue) reflecting increased demand.

Partially offset by:

A $76 million decrease in gross receipts tax revenue due to the NC Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014.

Operating Expenses. The variancewas driven primarily by:

A $573 million increase in fuel expense (including purchased power and natural gas purchases for resale) primarily related to (i) higher volumes of coal, oil and gasused in electric generation due primarily to increased generation resulting from favorable weather conditions, (ii) higher natural gas prices, and (iii) the application of the NEIL settlement proceeds in 2013 for Duke Energy Florida;

A $386 million increase in depreciation and amortization expense primarily due to increases in depreciation as a result of additional plant in service and amortization of regulatory assets, and higher 2013 reductions to cost of removal reserves in accordance with regulatory orders; and

A $124 million increase in operating and maintenance expense primarily due to higher storm costs, repairs and ~~remediation~~remediation expenses associated with the Dan River coal ash discharge, and higher ~~storm costs, partially offset by lower~~ nuclear costs, including nuclear outage levelization costs, and higher environmental and operational costs that are recoverable in rates; partially offset by decreased benefits costs and 2013 donations for low-income customers and job training in accordance with a 2013 NCUC and PSCSC rate case ~~order.~~orders.

Partially offset by:

A $345 million decrease due to the 2013 impairment and other charges primarily related to Crystal River Unit 3 Nuclear Station (Crystal River Unit 3) and ~~Levy;~~the proposed Levy Nuclear Station (Levy);

A $26 million decrease in property and other taxes primarily due to the termination of the collection of the North Carolina gross receipts tax as mentioned above, partially offset by higher property taxes; and

A $22 million decrease due to athe 2013 impairment resulting from the decision to suspend the application for two proposed nuclear units at ~~Harris.~~Shearon Harris Nuclear Station (Harris).

Other Income and Expenses, net. The variance is primarily due to recognition of post in-service equity returns for projects that had been completed prior to being reflected in customer rates, partially offset by lower ~~AFUDC~~allowance for funds used during construction (AFUDC) - equity, due to placing the Sutton plant into service in late 2013.

101

PART I

Interest Expense. The variancewas primarily due to no longer recording post in-service debt returns on projects now reflected in customer rates.

Income Tax Expense. The variance was primarily due to an increase in pretax income. The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was 3635.9 percent and ~~37.4~~37.5 percent, respectively. The decrease in the effective tax rate is primarily due to favorable audit settlements, the tax benefit related to the manufacturing deduction in 2014 as the prior year deduction was limited by taxable income, and changes in apportionment related to state income tax.

Matters Impacting Future Regulated Utilities Results

Appeals of recently approved rate cases are pending at the North Carolina Supreme Court. The North Carolina Attorney General (NCAG) and NC Waste Awareness and Reduction Network (NC WARN) dispute the rate of return, capital structure and other matters approved by the NCUC. The outcome of these appeals could have an adverse impact to Regulated Utilities’ financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at the 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 is a party to multiple lawsuits filed in regards to coal ash management practices, both preceding and following the Dan River incident. The United States Attorney for the Eastern District of North Carolina initiated a criminal investigation related to the discharge. The North Carolina legislature is in committee regarding a proposal of an ash basin management bill. In addition, Duke Energy has disclosed estimated costs of various potential approaches to ash management for North Carolina ash basins. The outcome of these lawsuits ~~investigation~~ and ~~any potential legislative actions~~investigation could have an adverse impact to Regulated Utilities’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

98An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to the Regulated Utilities' financial position, results of operations and cash flows. See Notes 5 and 7 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

~~PART I~~

International Energy


	Three Months Ended June 30,								Six Months Ended June 30,								Three Months Ended September 30,							Nine Months Ended September 30,
(in millions)	2014			2013		Variance			2014			2013		Variance			2014		2013		Variance			2014		2013		Variance
Operating Revenues	$	364		$	406	$	(42	)	$	746		$	798	$	(52	)	$	366	$	370	$	(4	)	$	1,111	$	1,168	$	(57	)
Operating Expenses	254			270		(16		)	485			533		(48		)	275		232		43			760		765		(5		)
Gains on Sales of Other Assets and Other, net	5			—		5			5			—		5			2		—		2			7		—		7
Operating Income	115			136		(21		)	266		��	265		1			93		138		(45		)	358		403		(45		)
Other Income and Expense, net	52			14		38			109			47		62			43		48		(5		)	152		95		57
Interest Expense	23			17		6			46			38		8			25		22		3			71		60		11
Income Before Income Taxes	144			133		11			329			274		55			111		164		(53		)	439		438		1
Income Tax (Benefit) Expense	(5		)	42		(47		)	46			84		(38		)
Income Tax Expense																	29		44		(15		)	74		128		(54		)
Less: Income Attributable to Noncontrolling Interests	3			4		(1		)	7			6		1			2		4		(2		)	9		10		(1		)
Segment Income	$	146		$	87	$	59		$	276		$	184	$	92		$	80	$	116	$	(36	)	$	356	$	300	$	56

Sales, GWh	4,281			4,926		(645		)	9,522			9,682		(160		)	4,292		5,062		(770		)	13,814		14,744		(930		)
Net proportional MW capacity in operation									4,411			4,584		(173		)								4,358		4,600		(242		)

Three Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

International Energy’s results were ~~positively~~ impacted by ~~a tax benefit related to a reorganization of Chilean operations, higher equity earnings~~unfavorable hydrology in Brazil and lower margins in Chile and National Methanol Company (NMC), ~~and the absence of a prior year net remeasurement loss in Peru,~~ partially offset by ~~lower sales volumes and unfavorable exchange rates~~favorable hydrology in ~~Brazil.~~Central America. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

A ~~$10~~$16 million decrease in ~~Brazil~~Peru due to ~~unfavorable exchange rates and~~ lower sales volumes partially offset by higher average prices;

~~An $8~~A $15 million decrease in Chile as a result of lower average prices and sales volumes due to an unplanned outage;

An $8 million decrease in Brazil due to lower sales volumes partially offset by higher average prices; and

~~An $8~~A $4 million decrease in Argentina due to unfavorable exchange rates and lower average prices partially offset by higher sales ~~volumes;~~volumes.

~~An $8 million decrease in Peru as a result of lower sales volumes; and~~Partially offset by:

A $7$39 million ~~decrease~~increase in Central America due to ~~lower~~higher sales volumes and average prices.

Operating Expenses. The variance was driven primarily by:

A ~~$10~~$38 million ~~decrease~~increase in Brazil due to higher purchased power as a result of unfavorable hydrology; and

A $25 million increase in Central America due to ~~lower~~higher fuel consumption in Guatemala and purchased power in El Salvador as a result of ~~decreased dispatch;~~increased dispatch.

102

PART I

Partially offset by:

A ~~$10 million decrease in Argentina as a result of favorable exchange rates and lower purchased power; and~~

~~A $5~~$17 million decrease in Peru due to lower ~~purchased power~~fuel and ~~fuel consumption.~~

~~Partially offset by:~~

~~A $9 million increase in Brazil as a result of higher purchased power partially offset by favorable exchange rates.~~

~~Other Income and Expenses, net~~. The variance is primarily due to the absence of a prior year remeasurement loss in Peru, and higher equity earnings in NMC as a result of higher methyl tertiary-butyl ether (MTBE) sales volumes partially offset by higher butanevariable costs.

Income Tax Expense. The variance was primarily due to a ~~deferred tax benefit recorded~~decrease in ~~the second quarter of 2014 as a result of the merger of two Chilean subsidiaries, resulting in a decrease to the effective tax rate.~~pretax income. The effective tax rate for the three months ended ~~June~~September 30, 2014 and 2013 was ~~(4.1)~~25.9 percent and ~~31.9~~27.2 percent, respectively. The decrease in the effective tax rate was primarily due to a reduction of related investment income.

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

International Energy’s results were ~~positively~~ impacted by a merger step up tax benefit ~~related to a reorganization of Chilean operations,~~in Chile, favorable results in Central America, and a net remeasurement gain in Latin America,~~higher equity earnings in NMC, and higher average prices and sales volumes~~ partially offset by unfavorable hydrology and exchange rates in Brazil. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily by:

A ~~$27 million decrease in Central America as a result of lower average prices and sales volumes;~~

~~A $15 million decrease in Argentina due to unfavorable exchange rates and lower average prices partially offset by higher sales volumes; and~~

~~A $12~~$28 million decrease in Peru as a result of lower sales volumes and unfavorable exchange rates partially offset by higher average prices; and

A $23 million decrease in Chile as a result of lower average prices and sales volumes due to an unplanned outage; and

A $19 million decrease in Argentina due to unfavorable exchange rates and lower average prices partially offset by higher sales volumes.

Partially offset by:

A $12 million increase in Central America as a result of higher sales volumes partially offset by lower average prices.

~~PART I~~

Operating Expenses. The variance was driven primarily by:

A ~~$27~~$26 million decrease in ~~Central America~~Peru due to lower purchased power and fuel ~~consumption;~~costs; and

A ~~$16~~$21 million decrease in Argentina as a result of lower purchased power and fuel consumption, and favorable exchange ~~rates; and~~rates.

Partially offset by:

A $9$42 million ~~decrease~~increase in ~~Peru~~Brazil due to ~~lower~~higher purchased power ~~and fuel consumption.~~as a result of unfavorable hydrology, partially offset by favorable exchange rates.

Other Income and Expenses, net. The variance is primarily due to a net remeasurement gain in Latin America, higher interest expense in Brazil, and higher equity earnings in NMC as a result of higher ~~MTBE and methanol sales~~methyl tertiary butyl ether volumes partially offset by lower average prices.

Interest Expense. The variance is primarily due to higher ~~butane costs.~~interest rates and debt prepayment penalty in Brazil.

Income Tax Expense. The variance was primarily due to a deferred tax benefit recorded in second quarter of 2014 as a result of the merger of two Chilean subsidiaries, which resulted in a decrease in the effective tax rate, and an increase in pretax income. The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was ~~13.9~~16.9 percent and ~~30.6~~29.3 percent, respectively.

Commercial Power


	Three Months Ended June 30,									Six Months Ended June 30,									Three Months Ended September 30,									Nine Months Ended September 30,
(in millions)	2014			2013			Variance			2014			2013			Variance			2014			2013			Variance			2014			2013			Variance
Operating Revenues	$	309		$	557		$	(248	)	$	758		$	1,009		$	(251	)	$	50		$	58		$	(8	)	$	195		$	189		$	6
Operating Expenses	502			508			(6		)	2,364			1,041			1,323			87			104			(17		)	355			308			47
Gains on Sales of Other Assets and Other, net	1			1			—			1			1			—			—			—			—			—			1			(1		)
Operating (Loss) Income	(192		)	50			(242		)	(1,605		)	(31		)	(1,574		)
Operating Loss																			(37		)	(46		)	9			(160		)	(118		)	(42		)
Other Income and Expense, net	5			—			5			10			11			(1		)	5			(2		)	7			15			9			6
Interest Expense	23			17			6			38			32			6			14			15			(1		)	41			45			(4		)
(Loss) Income Before Income Taxes	(210		)	33			(243		)	(1,633		)	(52		)	(1,581		)	(46		)	(63		)	17			(186		)	(154		)	(32		)
Income Tax Benefit	(90		)	(8		)	(82		)	(634		)	(51		)	(583		)	(29		)	(35		)	6			(116		)	(100		)	(16		)
Segment (Loss) Income	$	(120	)	$	41		$	(161	)	$	(999	)	$	(1	)	$	(998	)
Segment Loss																			$	(17	)	$	(28	)	$	11		$	(70	)	$	(54	)	$	(16	)

Coal-fired plant production, GWh	3,087			4,185			(1,098		)	7,798			8,734			(936		)	192			516			(324		)	867			1,266			(399		)
Gas-fired plant production, GWh	3,981			3,341			640			7,773			7,238			535
Renewable plant production, GWh	1,469			1,415			54			3,058			2,820			238			1,054			941			113			4,112			3,761			351
Total Commercial Power production, GWh	8,537			8,941			(404		)	18,629			18,792			(163		)	1,246			1,457			(211		)	4,979			5,027			(48		)
Net proportional MW capacity in operation										7,839			8,127			(288		)										1,698			2,060			(362		)

Three Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Commercial Power’s results were primarily attributable to ~~unfavorable mark-to-market results~~a gain on ~~non-qualifying commodity hedge contracts, partially offset by higher PJM Interconnection LLC (PJM) capacity revenues.~~the sale of intangible assets and lower depreciation expense. The following is a detailed discussion of the variance drivers by line item.

103

PART I

Operating Revenues. The variance was driven primarily ~~by:~~

~~A $262~~by an $8 million decrease in ~~net mark-to-market~~electric revenues ~~on non-qualifying power hedge contracts, consisting of mark-to-market losses of $183 million in 2014 compared to gains of $79 million in 2013; and~~

~~A $38 million decrease~~ for the ~~coal-fired generation assets~~Beckjord station, which is not included in the Disposal Group, driven ~~primarily by decreased volumes.~~

~~Partially offset by:~~

~~A $21 million increase in PJM capacity revenues related to higher average cleared capacity auction pricing beginning in May 2014;~~

~~A $17 million increase for Duke Energy Retail Sales, LLC (Duke Energy Retail) resulting from higher volumes and favorable pricing; and~~

~~A $9 million increase for the gas-fired generation assets driven primarily by increased volumes, partially offset~~ by lower ~~power prices.~~production as units have been retired.

Operating Expenses. The variance was driven primarily by:

An $8 million decrease in fuel expense for the Beckjord station driven by lower cost of coal from decreased production as units have been retired; and

A ~~$42~~$5 million decrease in depreciation driven by discontinued amortization of an intangible asset that was impaired and written off in 2014 and extensions on the projected useful lives of assets in the renewable portfolio.

Other Income and Expense. The variance was primarily due to a net gain recognized for the ~~nonregulated Midwest generation business resulting primarily~~sale of certain renewable intangible assets and increased equity earnings from ~~ceasing to depreciate fixed assets once~~higher production in the ~~assets were reclassified to held for sale at March 31, 2014;~~

~~A $23 million decrease in fuel expenses from the coal-fired generation assets driven by lower volumes, and coal costs, partially offset by unfavorable economic hedge settlements.~~

~~100~~

~~PART I~~

~~Partially offset by:~~

~~A $21 million impairment related to ongoing capital maintenance investments that are not expected to increase the fair value of the nonregulated Midwest generation business;~~

~~A $20 million increase in purchased power and capacity to serve Duke Energy Retail customers;~~

~~An $18 million increase in net mark-to-market fuel expense on non-qualifying fuel hedge contracts, consisting of mark-to-market losses of $28 million in 2014 compared to losses of $10 million in 2013.~~renewable wind portfolio.

Income Tax Expense. The variance was primarily due to a decrease in pretax ~~income.~~losses and higher production tax credits in 2014 for the Renewables portfolio. The effective tax rate for the three months ended ~~June~~September 30, 2014 and 2013 was ~~42.6~~64.1 percent and ~~(23.3)~~56.3 percent, respectively. ~~The increase in the effective tax rate was primarily due to pretax loss in 2014 as compared to pretax income in 2013.~~

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Commercial Power’s results were negatively impacted by ~~the~~an impairment recorded for ~~the nonregulated Midwest generation business and unfavorable mark-to-market results on non-qualifying commodity hedge contracts.~~an intangible asset. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The variance was driven primarily ~~by:~~

~~A $320~~by a $17 million increase in electric revenues from higher production in the renewables portfolio, partially offset by a $9 million decrease in net mark-to-market revenues on non-qualifying power hedge ~~contracts, consisting of mark-to-market losses of $309 million in 2014 compared to gains of $11 million in 2013; and~~

~~A $53 million decrease for the coal-fired generation assets driven primarily by lower realized power prices and volumes.~~

~~Partially offset by:~~

~~A $79 million increase for Duke Energy Retail resulting from favorable pricing and volumes;~~

~~A $29 million increase in PJM capacity revenues related to higher average cleared capacity auction pricing beginning in May 2014; and~~

~~A $15 million increase for Duke Energy Renewables driven primarily by higher production.~~contracts.

Operating Expenses. The variance was driven primarily by:

A ~~$1,402 million impairment recognized for the plan to exit the nonregulated Midwest generation business; and~~

~~A $95~~$94 million increase ~~in purchased power~~driven by an impairment taken to ~~serve Duke Energy Retail customers.~~reducing the carrying value of OVEC to zero.

Partially offset by:

A ~~$78 million decrease in net mark-to-market fuel expense on non-qualifying fuel hedge contracts, consisting of mark-to-market gains of $61 million in 2014 compared to losses of $17 million in 2013;~~

~~A $44~~$13 million decrease in depreciation ~~for~~driven by discontinued amortization of an intangible asset that was impaired and written off in 2014 and extensions on the ~~nonregulated Midwest generation business resulting primarily from ceasing to depreciate fixed~~projected useful lives of assets ofin the ~~disposal group once the assets were reclassified to held for sale at March 31, 2014;~~renewable portfolio; and

~~A $25~~An $8 million decrease in fuel ~~expenses from~~expense for the ~~coal-fired generation assets~~Beckjord station, which is not included in the Disposal Group, driven by lower ~~volumes~~cost of coal from decreased production as units have been retired; and ~~coal costs, partially offset~~

A $6 million decrease in property tax expense driven by ~~unfavorable economic hedge settlements.~~cost reductions in the renewables portfolio resulting from a property tax abatement that went into effect in the current year; and

A $6 million decrease in operations and maintenance expense for the renewables portfolio driven primarily by reductions in development activities.

Other Income and Expense. The variance was primarily due to a net gain recognized for the sale of certain renewable intangible assets and increased equity earnings from higher production in the renewable wind portfolio.

Income Tax Expense. The variance was primarily due to an increase in pretax ~~losses.~~losses and higher production tax credits in 2014 for the Renewables portfolio. The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was ~~38.8~~62.4 percent and ~~97.6~~65.3 percent, respectively. ~~The decrease in the effective tax rate was primarily due to the first quarter of 2014 impairment of the nonregulated Midwest generation business.~~

Matters Impacting Future Commercial Power Results

On February 17, 2014, Commercial Power announced it had initiated a process to exit its nonregulated Midwest generation business. Commercial Power expects to dispose of the nonregulated Midwest generation business by the end of the first quarter of 2015. Commercial Power recognized a pretax loss of $1.4 billion for the six months ended June 30, 2014, which represents the excess of the carrying value over the estimated fair value of the business, less estimated costs to sell. The impairment will be updated, if necessary, based on changes in the estimated fair value as additional information related to the potential transaction becomes available.

In 2013, a ~~FERC~~Federal Energy Regulatory Commission (FERC) Administrative Law Judge issued an initial decision holding that Commercial Power is responsible for certain Multi Value Projects (MVP) costs, a type of Transmission Expansion Planning (MTEP) cost, approved by Midcontinent Independent System Operator, Inc. (MISO) prior to the date of Commercial Power’s withdrawal. The initial decision will be reviewed by ~~Federal Energy Regulatory Commission (FERC).~~FERC. If FERC upholds the initial decision, Commercial Power intends to file an appeal in federal court. If Commercial Power ~~ultimately~~ is ~~found to be~~deemed responsible for these costs, and if a portion of these costs ~~may~~are not be eligible for recovery, ~~resulting in~~there may be an adverse impact to its financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

Income (Loss) From Discontinued Operations, Net Of Tax

~~101~~

~~PART I~~

~~Changes or variability~~Discontinued Operations increased $316 million for the three months ended September 30, 2014 compared to the same period in ~~assumptions used in calculating fair value~~the prior year, primarily due to a $460 million pretax reversal of the ~~renewables reporting unit~~impairment on the Disposal Group based on the transaction price included in the PSA less cost to sell exceeding the adjusted carrying amount. Included in the variance is the $40 million impact of ceasing depreciation on the assets of the Disposal Group beginning in the second quarter of 2014.

Discontinued Operations decreased $660 million for ~~goodwill testing purposes including, but not limited~~the nine months ended September 30, 2014 compared to ~~legislative actions related~~the same period in the prior year, primarily due to ~~tax credit extensions, long-term growth rates and discount rates, could significantly impact~~a $847 million pretax write-down of the carrying amount of the assets to the estimated fair value of the ~~renewables reporting unit. In~~Disposal Group, based on the ~~event of a significant decline~~transaction price included in the PSA, less estimated ~~fair value~~costs to sell and a $195 million pretax mark-to-market loss on economic hedges for the Disposal Group. Included in the variance is the $82 million impact of ceasing depreciation on the assets of the ~~renewables reporting unit, goodwill and other asset impairment charges could be recorded. The carrying value~~Disposal Group beginning in the second quarter of ~~goodwill and intangible assets associated with proposed renewable projects within Commercial Power’s renewables reporting unit was approximately $84 million at June 30,~~ 2014. In addition, management periodically reviews individual projects within Commercial Power’s renewables portfolio to evaluate ongoing alignment with the strategic direction of the business. A determination that a project is no longer consistent with the business strategy and a decision to divest of a project or projects could result in an impairment charge.

104

PART I

Other


	Three Months Ended June 30,									Six Months Ended June 30,									Three Months Ended September 30,									Nine Months Ended September 30,
(in millions)	2014			2013			Variance			2014			2013			Variance			2014			2013			Variance			2014			2013			Variance
Operating Revenues	$	28		$	36		$	(8	)	$	53		$	71		$	(18	)	$	25		$	47		$	(22	)	$	79		$	113		$	(34	)
Operating Expenses	100			156			(56		)	184			246			(62		)	84			128			(44		)	269			360			(91		)
Losses on Sales of Other Assets and Other, net	—			(4		)	4			—			(4		)	4
Gains (Losses) on Sales of Other Assets and Other, net																			1			(1		)	2			2			(4		)	6
Operating Loss	(72		)	(124		)	52			(131		)	(179		)	48			(58		)	(82		)	24			(188		)	(251		)	63
Other Income and Expense, net	15			8			7			22			19			3			18			(14		)	32			33			4			29
Interest Expense	103			105			(2		)	208			200			8			101			108			(7		)	302			305			(3		)
Loss Before Income Taxes	(160		)	(221		)	61			(317		)	(360		)	43			(141		)	(204		)	63			(457		)	(552		)	95
Income Tax Benefit	(58		)	(81		)	23			(133		)	(141		)	8			(50		)	(140		)	90			(190		)	(276		)	86
Less: Income (Loss) Attributable to Noncontrolling Interests	1			(1		)	2			1			(3		)	4
Less: Income Attributable to Noncontrolling Interests																			1			—			1			2			2			—
Net Expense	$	(103	)	$	(139	)	$	36		$	(185	)	$	(216	)	$	31		$	(92	)	$	(64	)	$	(28	)	$	(269	)	$	(278	)	$	9

Three Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Other’s results were ~~positively~~negatively impacted by a decrease in ~~operating expenses.~~income tax benefit. The following is a detailed discussion of the variance drivers by line item.

Operating Revenues. The decrease was primarily due to mark-to-market activity of mitigation sales related to the Progress Energy merger, partially offset by prior-year mark-to-market activity for Duke Energy Trading and Marketing, LLC (DETM), which was divested in 2013.

Operating Expenses. The decrease was primarily due to lower charges related to the Progress Energy merger, ~~and lower litigation reserves,~~ partially offset by lower expenses related to DETM and unfavorable loss experience at Bison Insurance Company Limited (Bison).

Other Income and Expenses. The increase was primarily due to a gain on investment sale in 2014 and lower interest income following the settlement of a 2004 and 2005 federal tax audit in the prior year.

Income Tax Expense. The variance was primarily due to a decrease in pretax losses. The effective tax rate for the three months ended ~~June~~September 30, 2014 and 2013 was ~~35.9~~35.2 percent and 3769.0 percent, respectively. The decrease in the effective tax rate is primarily due to a favorable ~~audit settlements.~~deferred state tax adjustment in the third quarter of 2013.

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Other’s results were positively impacted by a decrease in operating expenses. The following is a detailed discussion of the variance drivers by line item.

Operating Expenses. The decrease was primarily due to lower charges related to the Progress Energy merger and lower litigation reserves, partially offset by unfavorable loss experience at ~~Bison.~~Bison and lower expenses related to DETM.

Income Tax Expense. The variance was primarily due to a decrease in pretax losses. The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was ~~41.9~~41.5 percent and ~~39.1~~50.1 percent, respectively. The ~~increase~~decrease in the effective tax rate is primarily due to ~~an unfavorable consolidated~~a favorable deferred state tax adjustment ~~recorded~~ in the ~~second~~third quarter of 2013.

Matters Impacting Future Other Results

Duke Energy previously held an effective 50 percent interest in Crescent Resources, LLC (Crescent). Crescent was a real estate joint venture formed by Duke Energy in 2006 that filed for Chapter 11 bankruptcy protection in June 2009. On June 9, 2010, Crescent restructured and emerged from bankruptcy and Duke Energy forfeited its entire 50 percent ownership interest to Crescent debt holders. This forfeiture caused Duke Energy to recognize a loss, for tax purposes, on its interest in the second quarter of 2010. Although Crescent has reorganized and emerged from bankruptcy with creditors owning all Crescent interest, there remains uncertainty as to the tax treatment associated with the restructuring. Based on this uncertainty, it is possible that Duke Energy could incur a future tax liability related to the tax losses associated with its partnership interest in Crescent and the resolution of issues associated with Crescent’s emergence from bankruptcy.

~~102~~105

PART I

DUKE ENERGY CAROLINAS

Management’s Discussion and Analysis should be read in conjunction with the accompanying Condensed Consolidated Financial Statements and Notes for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 and the Annual Report on Form 10-K for the year ended December 31, 2013.

The results of operations and variance discussion is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

Results of Operations


	Six Months Ended June 30,							Nine Months Ended September 30,
(in millions)	2014		2013		Variance			2014		2013		Variance
Operating Revenues	$	3,755	$	3,320	$	435		$	5,693	$	5,239	$	454
Operating Expenses	2,808		2,537		271			4,116		3,850		266
Gains on Sales of Other Assets and Other, net	—		2		(2		)
Operating Income	947		785		162			1,577		1,389		188
Other Income and Expenses, net	93		65		28			137		94		43
Interest Expense	203		173		30			307		255		52
Income Before Income Taxes	837		677		160			1,407		1,228		179
Income Tax Expense	281		252		29			474		461		13
Net Income	$	556	$	425	$	131		$	933	$	767	$	166

The following table shows the percent changes in GWh sales and average number of customers. The below percentages for retail customer classes represent billed sales only. Total sales includes billed and unbilled retail sales, and wholesale sales to incorporated municipalities and to public and private utilities and power marketers. Amounts are not weather normalized.



Increase (decrease) over prior year	2014
Residential sales	~~6.8~~5.1	%
General service sales	~~3.2~~2.7	%
Industrial sales	~~2.4~~2.3	%
Wholesale power sales	~~4.0~~(2.6	)%
Total sales	~~4.9~~3.0	%
Average number of customers	0.9	%

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Operating Revenues. The variance was driven primarily by:

A ~~$203~~$186 million increase in fuel revenues driven primarily by increased demand from retail customers, mainly due to favorable weather conditions, and higher natural gas prices. Fuel revenues represent sales to retail and wholesale customers;

A ~~$116~~$182 million increase in retail pricing and updated rate riders, which primarily reflects the impact of the 2013 North Carolina and South Carolina retail rate cases;

~~An $82~~A $103 million increase in electric sales (net of fuel revenues) to retail customers due to favorable weather conditions. Heating degree days for the first ~~half~~nine months of 2014 were 16 percent above normal compared to 78 percent above normal during the same period in 2013 and cooling degree days for the first ~~half~~nine months of 2014 were 7 percent ~~above~~below normal as compared to 1618 percent below normal in 2013; and

A ~~$28~~$19 million increase in weather-normal sales volumes to retail customers reflecting increased demand.

Partially offset by:

A $42 million decrease in gross receipts tax revenue due to the NC Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014.

Operating Expenses. The variance was driven primarily by:

A ~~$200~~$185 million increase in fuel expense (including purchased power) primarily related to increased generation due to higher sales volumes and increased prices of natural gas used in electric generation, net of change in fuel mix;

A ~~$42~~$74 million increase in depreciation and amortization primarily due to higher depreciation as a result of additional plant in service and amortization of certain regulatory assets, partially offset by lower amortization expense due to reductions in regulatory liabilities for costs of removal in accordance with the 2013 North Carolina and South Carolina rate case orders; and

A ~~$14~~$23 million increase in operating and maintenance expenses primarily due to higher non-outage costs at generation plants, higher storm costs, ~~and~~ repairs and remediation expenses associated with the Dan River coal ash discharge and higher energy efficiency program costs, partially offset by decreased corporate costs, lower costs associated with the Progress Energy merger, lower nuclear outage expenses including the impacts of levelization and decreased employee benefit costs.

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PART I

Partially offset by:

A $19 million decrease in property and other tax expenses primarily due to lower ~~nuclear non-outage costs and fossil outage costs.~~revenue related taxes driven by the elimination of North Carolina gross receipts tax effective July 1, 2014, partially offset by higher property tax expense.

Other Income and Expenses, net. The variance was primarily due to the recognition of post in-service equity returns for projects that had been completed prior to being reflected in customer rates.

Interest Expense. The variance was primarily due to no longer recording post in-service debt returns on projects now reflected in customer rates, partially offset by lower interest on ~~bonds due to refinancings in the prior year.~~bonds.

Income Tax Expense. The variance was primarily due to an increase in pretax income. The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was ~~33.6~~33.7 percent and ~~37.2~~37.5 percent, respectively. The decrease in the effective tax rate ~~was~~is primarily due to favorable audit settlements, ~~and~~ changes in apportionment related to state income ~~tax.~~tax and the tax benefit related to the manufacturing deduction in 2014 as the prior year deduction was limited by taxable income.

~~103~~

~~PART I~~

Matters Impacting Future Results

Appeals of recently approved rate cases are pending at the North Carolina Supreme Court. The NCAG and NC WARN dispute the rate of return, capital structure and other matters approved by the NCUC. The outcome of these appeals could have an adverse impact to Duke Energy Carolinas’ financial position, results of operations and cash flows. See Note 4 to the Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at the 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 is a party to multiple lawsuits filed in regards to coal ash management practices, both preceding and following the Dan River incident. The United States Attorney for the Eastern District of North Carolina initiated a criminal investigation related to the discharge. The North Carolina legislature is in committee regarding a proposal of an ash basin management bill. In addition, Duke Energy has disclosed estimated costs of various potential approaches to ash management for North Carolina ash basins. The outcome of these lawsuits ~~investigation~~ and ~~any potential legislative actions~~investigation could have an adverse impact to Duke Energy Carolinas’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to Duke Energy Carolinas' financial position, results of operations and cash flows. See Notes 5 and 7 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

~~104~~107

PART I

PROGRESS ENERGY

The results of operations and variance discussion is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

Results of Operations


	Six Months Ended June 30,									Nine Months Ended September 30,
(in millions)	2014			2013			Variance			2014			2013		Variance
Operating Revenues	$	4,962		$	4,467		$	495		$	7,825		$	7,233	$	592
Operating Expenses	3,998			3,924			74			6,198			6,020		178
Gains on Sales of Other Assets and Other, net	1			1			—			3			2		1
Operating Income	965			544			421			1,630			1,215		415
Other Income and Expenses, net	28			37			(9		)	54			63		(9		)
Interest Expense	336			358			(22		)	502			520		(18		)
Income From Continuing Operations Before Taxes	657			223			434			1,182			758		424
Income Tax Expense From Continuing Operations	246			82			164			441			289		152
Income From Continuing Operations	411			141			270			741			469		272
Loss From Discontinued Operations, net of tax	(6		)	(4		)	(2		)
(Loss) Income From Discontinued Operations, net of tax										(6		)	10		(16		)
Net Income	405			137			268			735			479		256
Less: Net Income Attributable to Noncontrolling Interest	1			1			—			2			2		—
Net Income Attributable to Parent	$	404		$	136		$	268		$	733		$	477	$	256

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Operating Revenues. The variance was driven primarily by:

A ~~$257~~$311 million increase in fuel ~~and capacity~~ revenues (including emission allowances) driven primarily by increased demand from wholesale and retail customers, partially resulting from favorable weather conditions, and higher fuel rates for wholesale customers reflective of higher fuel costs for Duke Energy Progress; and to increased demand from electric retail customers in the current year mainly due to favorable weather as well as a higher fuel rate in the current year related to lower ~~Nuclear Electric Insurance Limited (NEIL)~~NEIL insurance reimbursements and accelerated Crystal River Unit 3 regulatory asset cost recovery in 2014 as allowed by the 2013 Settlement for Duke Energy ~~Florida;~~Florida. Fuel revenues represent sales to retail and wholesale customers;

A ~~$99~~$131 million increase in retail pricing, which primarily reflects the impact of the 2013 North Carolina retail rate case in North Carolina and the 2014 base rate increase in Florida;

A ~~$69~~$100 million increase (net of fuel revenue) in GWh sales to retail customers due to favorable weather conditions. For Duke Energy Progress, Heating degree days for the ~~six~~nine months ended ~~June~~September 30, 2014 were 15 percent above normal compared to 6 percent above normal for the prior year and cooling degree days were 103 percent ~~above~~below normal compared to 14 percent below normal for the prior year. For Duke Energy Florida, Heating degree days for the ~~second quarter of~~nine months ended September 30, 2014 were 24 percent higher and cooling degree days were one percent higher compared to the same period in 2013;

A ~~$32~~$50 million increase in nuclear cost recovery clause and energy conservation cost recovery clause revenues at Duke Energy Florida due to higher recovery rates in the current year;

~~A $20 million increase (net of fuel revenue) in GWh sales to retail customers due to higher weather-normal sales volumes to retail customers; and~~

~~A $12 million increase in wholesale power revenues at Duke Energy Progress primarily due to higher energy rates, increased capacity rates and higher peak demand.~~

Operating Expenses. The variance was driven primarily by:

A ~~$242~~$302 million increase in fuel expenses (including purchased power). For Duke Energy Florida the increase is due to the application of the NEIL settlement proceeds in 2013 and higher sales volumes driven by increased demand and higher fuel prices in the current year. For Duke Energy Progress the increase is primarily due to increased sales volumes and higher fuel ~~prices;~~prices.

A ~~$153~~$221 million increase in depreciation and amortization. For Duke Energy Florida the increase is primarily due to a reduction of the cost of removal component of amortization expense in 2013 as allowed under the 2012 Settlement and increased environmental cost recovery clause amortization related to prior year under-recovery and nuclear cost recovery clause amortization due to an increase in recoverable nuclear assets in the current year. For Duke Energy Progress the increase is primarily due to additional plant in service and amortization of certain regulatory assets and a prior year reversal of a portion of cost of removal reserves in accordance with the 2013 NCUC rate case order; and

A ~~$36~~$43 million increase in operations and maintenance ~~expenses at~~expenses. For Duke Energy Progress the increase is primarily due to the impacts of amortization on nuclear levelization outage deferrals and higher storm costs, ~~and nuclear outage expenses including the impacts of nuclear levelization,~~ partially offset by prior year donations for low-income customers and job training in accordance with the 2013 NCUC rate case ~~order.~~order and lower costs to achieve the merger with Duke Energy including transmission projects and severance. For Duke Energy Florida the increase is primarily due to an increase in expenses that are recoverable under the energy conservation cost recovery clause, partially offset by a decrease in overall corporate costs, including benefits.

~~105~~108

PART I

Partially offset by:

A $344 million decrease ~~at Duke Energy Florida~~ due to 2013 impairment and other charges at Duke Energy Florida primarily related to Crystal River Unit 3 and Levy; and

A $40 million decrease at Duke Energy Progress due to a current year $18 million reduction to a 2012 impairment charge related to the disallowance of transmission project costs, which are a portion of the Long-Term FERC Mitigation and a $22 million prior year impairment charge ~~at Duke Energy Progress~~ resulting from the decision to suspend the application for two proposed nuclear units at the Harris nuclear station.

Interest Expense. The variance was primarily due to the $29 million charge to interest expense on the redemption of Progress Energy’s 7.10 percent Cumulative ~~QUIPS~~Quarterly Income Preferred Securities in January of 2013.

Matters Impacting Future Results

An appeal of a recently approved rate case is pending at the North Carolina Supreme Court. The NCAG and NC WARN dispute the rate of return, capital structure and other matters approved by the NCUC. The outcome of this appeal could have an adverse impact to Progress Energy’s financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy ~~Carolinas’~~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 is a party to multiple lawsuits filed in regards to coal ash management practices, both preceding and following the Dan River incident. The North Carolina legislature is in committee regarding a proposal of an ash basin management bill. In addition, Duke Energy has disclosed estimated costs of various potential approaches to ash management for North Carolina ash basins. The outcome of these lawsuits ~~and any potential legislative actions~~ could have an adverse impact to Progress ~~Energy’s~~Energy's financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to Progress Energy's financial position, results of operations and cash flows. See Notes 5 and 7 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

~~106~~109

PART I

DUKE ENERGY PROGRESS

The results of operations and variance discussion is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

Results of Operations


	Six Months Ended June 30,							Nine Months Ended September 30,
(in millions)	2014		2013		Variance			2014		2013		Variance
Operating Revenues	$	2,613	$	2,351	$	262		$	3,980	$	3,781	$	199
Operating Expenses	2,144		1,973		171			3,226		3,101		125
Gains on Sales of Other Assets and Other, net	1		—		1			1		1		—
Operating Income	470		378		92			755		681		74
Other Income and Expenses, net	16		22		(6		)	34		43		(9		)
Interest Expense	115		95		20			172		147		25
Income Before Income Taxes	371		305		66			617		577		40
Income Tax Expense	137		118		19			226		215		11
Net Income and Comprehensive Income	$	234	$	187	$	47		$	391	$	362	$	29



Increase (decrease) over prior period	2014
Residential sales	~~8.8~~6.7	%
General service sales	~~3.5~~2.9	%
Industrial sales	(~~2.2~~3.3	)%
Wholesale power sales	~~15.7~~6.9	%
Total sales	~~7.3~~3.6	%
Average number of customers	~~1.0~~1.1	%

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Operating Revenues. The variance was driven primarily by:

A ~~$137~~$96 million increase in fuel revenues (including emission allowances) driven primarily by increased demand from wholesale and retail customers, partially resulting from favorable weather conditions, and higher fuel rates for wholesale customers reflective of higher fuel costs. Fuel revenues represent sales to retail and wholesale customers;

A ~~$64~~$72 million increase in retail pricing, which primarily reflects the impact of the 2013 North Carolina retail rate case;

A ~~$54~~$70 million increase (net of fuel revenue) in ~~GWh~~electric sales to retail customers due to favorable weather conditions. Heating degree days for the ~~six~~nine months ended ~~June~~September 30, 2014 were 15 percent above normal compared to 6 percent above normal for the prior year and cooling degree days were 103 percent ~~above~~below normal compared to 14 percent below normal for the prior year; and

A ~~$12~~$27 million increase in wholesale power revenues primarily due to higher energy rates, increased capacity rates and higher peak demand.

Partially offset by:

A $34 million decrease in gross receipts tax revenue due to the NC Tax Simplification and Rate Reduction Act which terminated the collection of the North Carolina gross receipts tax effective July 1, 2014; and

An $18 million decrease in weather-normal sales volumes to retail customers reflecting decreased demand.

Operating Expenses. The variance was driven primarily by:

A ~~$131~~$109 million increase in fuel expenses (including purchased power) primarily due to increased sales volumes;

A ~~$36~~$48 million increase in depreciation and amortization expenses primarily due to higher depreciation as a result of additional plant in service and amortization of certain regulatory assets and a prior year reversal of a portion of cost of removal reserves in accordance with the 2013 NCUC rate case order; and

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PART I

A $30 million increase in operations and maintenance expenses primarily due to ~~higher storm costs and nuclear outage expenses including~~ the impacts of amortization on nuclear levelization outage deferrals and higher storm costs, partially offset by prior year donations for low-income customers and job training in accordance with the 2013 NCUC rate case ~~order;~~order and

~~A $36 million increase in depreciation~~ lower costs to achieve the merger with Duke Energy including transmission projects and ~~amortization expenses primarily due to a prior year reversal of a portion of cost of removal reserves in accordance with the 2013 NCUC rate case order.~~severance.

Partially offset by:

A $40 million decrease due to ana current year $18 million reduction to a 2012 impairment charge related to the disallowance of transmission project costs, which are a portion of the Long-Term FERC Mitigation and a $22 million prior year impairment charge resulting from the decision to suspend the application for two proposed nuclear units at the Harris nuclear ~~station.~~station; and

A $22 million decrease in property and other tax expenses primarily due to lower revenue related taxes driven by the elimination of North Carolina gross receipts tax effective July 1, 2014, partially offset by higher property tax expense.

Interest Expense. The variance was primarily due to no longer recording post in-service debt returns on projects now reflected in customer rates and lower AFUDC - debt due to projects placed in service.

~~107~~

~~PART I~~

Matters Impacting Future Results

An appeal of a recently approved rate case is pending at the North Carolina Supreme Court. The NCAG and NC WARN dispute the rate of return, capital structure and other matters approved by the NCUC. The outcome of this appeal could have an adverse impact to Duke Energy Progress’s financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

On February 2, 2014, a break in a stormwater pipe beneath an ash basin at Duke Energy ~~Carolinas’~~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 is a party to multiple lawsuits filed in regards to coal ash management practices, both preceding and following the Dan River incident. The North Carolina legislature is in committee regarding a proposal of an ash basin management bill. In addition, Duke Energy has disclosed estimated costs of various potential approaches to ash management for North Carolina ash basins. The outcome of these lawsuits ~~and any potential legislative actions~~ could have an adverse impact to Duke Energy Progress’ financial position, results of operations and cash flows. See Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies,” for additional information.

An order from regulatory authorities disallowing recovery of costs related to closure of ash basins could have an adverse impact to Duke Energy Progress' financial position, results of operations and cash flows. See Notes 5 and 7 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies” and "Asset Retirement Obligations," respectively, for additional information.

~~108~~111

PART I

DUKE ENERGY FLORIDA

The results of operations and variance discussion is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

Results of Operations


	Six Months Ended June 30,							Nine Months Ended September 30,
(in millions)	2014		2013		Variance			2014		2013		Variance
Operating Revenues	$	2,341	$	2,110	$	231		$	3,832	$	3,442	$	390
Operating Expenses	1,846		1,943		(97		)	2,959		2,906		53
Gains on Sales of Other Assets and Other, net	—		1		(1		)	—		1		(1		)
Operating Income	495		168		327			873		537		336
Other Income and Expenses, net	11		13		(2		)	17		19		(2		)
Interest Expense	99		92		7			150		138		12
Income Before Income Taxes	407		89		318			740		418		322
Income Tax Expense	157		36		121			285		168		117
Net Income	$	250	$	53	$	197		$	455	$	250	$	205

The following table shows the percent changes in GWh sales and average number of customers. The below percentages for retail customer classes represent billed sales only. Wholesale power sales include both billed and unbilled sales. Total sales includes billed and unbilled retail sales, and wholesale sales to incorporated municipalities and to public and private utilities and power marketers. Amounts are not weather normalized.



Increase over prior period	2014
Residential sales	~~2.6~~5.1	%
General service sales	~~0.5~~1.4	%
Industrial sales	~~1.4~~1.5	%
Wholesale power sales	~~6.8~~3.4	%
Total sales	~~3.5~~3.2	%
Average number of customers	~~1.3~~1.4	%

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Operating Revenues. The variance was driven primarily by:

A ~~$120~~$215 million increase in fuel and capacity revenues primarily due to increased demand from electric retail customers in the current year mainly due to favorable weather as well as a higher fuel rate in the current year related to lower NEIL insurance reimbursements and accelerated Crystal River Unit 3 regulatory asset cost recovery in 2014 as allowed by the 2013 Settlement. Fuel revenues represent sales to retail and wholesale customers;

A ~~$35~~$59 million net increase in base revenues due primarily to the 2014 base rate increase;

A ~~$32~~$50 million increase in nuclear cost recovery clause and energy conservation cost recovery clause revenues due to higher recovery rates in the current year;

A ~~$15~~$30 million increase in electric sales (net of fuel revenue) to retail customers due to favorable weather conditions. Heating degree days ~~for the second quarter of~~in 2014 were 24 percent higher and cooling degree days were one percent higher compared to the same period in 2013; ~~and~~

A ~~$14~~$16 million increase in weather-normal sales volumes to retail customers reflecting increased ~~demand.~~demand; and

A $13 million increase in wholesale power revenues primarily driven by increased capacity rates partially offset by the impact of contracts that expired in 2013.

Operating Expenses. The variance was driven primarily by:

A ~~$344~~$193 million ~~decrease~~increase in fuel used in electric generation and purchased power due to the application of the NEIL settlement proceeds in 2013 ~~impairment~~ and ~~other charges primarily related to Crystal River Unit 3~~higher sales volumes driven by increased demand and ~~Levy.~~

~~Partially offset by:~~higher fuel prices in the current year;

A ~~$129~~$173 million increase in depreciation and amortization primarily due to a reduction of the cost of removal component of amortization expense in 2013 as allowed under the 2012 Settlement and increased environmental cost recovery clause amortization related to prior year under-recovery and nuclear cost recovery clause amortization due to an increase in recoverable nuclear assets in the current year; ~~and~~

A ~~$110~~$21 million increase in ~~fuel used~~property and other taxes primarily driven by higher revenue-related taxes in ~~electric generation and purchased power~~2014 due to the higher ~~sales volumes~~revenues and higher property taxes; and

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PART I

An $10 million increase in operations and maintenance costs primarily due to an increase in expenses that are recoverable under the energy conservation cost recovery clause, partially offset by a decrease in overall corporate costs, including benefits.

Partially offset by:

A $344 million decrease due to 2013 impairment and other charges primarily related to Crystal River Unit 3 and Levy.

Interest Expense. The increase is due to a lower debt return in 2014 driven by ~~increased demand~~the Crystal River Unit 3 regulatory asset impairment in 2013 and ~~higher fuel prices.~~accelerated Crystal River Unit 3 regulatory asset cost recovery in 2014 as allowed by the 2013 Settlement.

~~109~~113

PART I

DUKE ENERGY OHIO

The results of operations and variance discussion is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

Results of Operations


	Six Months Ended June 30,								Nine Months Ended September 30,
(in millions)	2014			2013		Variance			2014			2013		Variance
Operating Revenues	$	1,294		$	1,558	$	(264	)	$	1,433		$	1,349	$	84
Operating Expenses	2,794			1,471		1,323			1,322			1,220		102
Gains on Sales of Other Assets and Other, net	—			4		(4		)	—			4		(4		)
Operating (Loss) Income	(1,500		)	91		(1,591		)
Operating Income									111			133		(22		)
Other Income and Expenses, net	5			3		2			9			4		5
Interest Expense	51			36		15			60			47		13
(Loss) Income Before Income Taxes	(1,546		)	58		(1,604		)
Income Tax (Benefit) Expense	(549		)	21		(570		)
Income from Continuing Operations Before Income Taxes									60			90		(30		)
Income Tax Expense from Continuing Operations									21			33		(12		)
Income from Continuing Operations									39			57		(18		)
(Loss) Income from Discontinued Operations, net of tax									(597		)	39		(636		)
Net (Loss) Income	$	(997	)	$	37	$	(1,034	)	$	(558	)	$	96	$	(654	)

The following table shows the percent changes in Regulated Utilities' GWh sales and average number of customers. The below percentages for retail customer classes represent billed sales only. Total sales includes billed and unbilled retail sales, and wholesale sales to incorporated municipalities and to public and private utilities and power marketers. Amounts are not weather normalized.



Increase (decrease) over prior year	2014
Residential sales	~~5.9~~2.4	%
General service sales	~~2.3~~1.5	%
Industrial sales	~~3.9~~4.3	%
Wholesale power sales	(~~37.9~~29.2	)%
Total sales	~~2.7~~1.1	%
Average number of customers	0.6	%

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Operating Revenues. The variance was driven primarily by:

A ~~$342 million decrease in net mark-to-market revenue on non-qualifying power hedge contracts, consisting of mark-to-market losses of $343 million in 2014 compared to losses of $1 million in 2013; and~~

~~A $53 million decrease for the coal-fired generation assets driven primarily by lower realized power prices and volumes.~~

~~Partially offset by:~~

~~A $40~~$48 million increase in regulated fuel revenues primarily driven by higher fuel costs and increased sales volumes; and

A ~~$29~~$42 million increase in retail pricing and rate riders primarily due to 2013 rate ~~increases;~~increases.

Partially offset by:

A ~~$29~~$10 million ~~increase~~decrease in ~~PJM capacity~~net mark-to-market revenue ~~related to higher average cleared capacity auction pricing beginning in May 2014; and~~

~~An $11 million increase in electric revenues from the gas-fired generation assets driven primarily by higher realized~~on non-qualifying power ~~prices and volumes.~~hedge contracts.

Operating Expenses. The variance was driven primarily by:

A ~~$1,438~~$94 million impairment ~~recognized for~~taken to reduce the ~~nonregulated Midwest generation business;~~carrying value of OVEC to zero; and

A ~~$59~~$60 million increase in regulated fuel expense driven primarily by higher fuel costs and increased ~~volumes, and higher purchased power expense.~~volumes.

Partially offset by:

A $30 million decrease in depreciation and amortization for the nonregulated Midwest generation business resulting primarily from ceasing to depreciate fixed assets once the assets were reclassified to held-for-sale at March 31, 2014;

~~A $30~~$32 million decrease in operating and maintenance expenses primarily due to lower corporate governance costs; and

A ~~$25~~$14 million decrease in ~~fuel expense for the coal-fired generation assets~~property and other taxes driven primarily by ~~lower coal costs, partially offset with unfavorable economic hedge settlements.~~an Ohio gas excise tax settlement in 2014.

~~110~~

~~PART I~~

Interest Expense. The increase was primarily due to higher average debt balances in 2014 compared to 2013.

Income Tax Expense. The variance was primarily due to a decrease in pretax income. The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was ~~35.5~~34.9 percent and ~~35.9~~36.5 percent, respectively. The decrease in the effective tax rate was primarily due to certain nondeductible book depreciation.

Discontinued Operations, Net of Tax. The variance was primarily due to the impairment recognized for the nonregulated Midwest generation business and unfavorable mark-to-market results.

114

PART I

Matters Impacting Future Results

On February 17, 2014, Duke Energy Ohio announced it had initiated a process to exit its nonregulated Midwest generation business. Duke Energy Ohio expects to dispose of the nonregulated Midwest generation business byin the ~~end~~fourth quarter of 2014 or the first quarter of 2015. Duke Energy Ohio recognized a pretax ~~loss~~impairment charge of ~~$1.4 billion~~$878 million for the ~~six~~nine months ended ~~June~~September 30, 2014, which represents the excess of the carrying value over the estimated fair value of the business based on the transaction price included in the PSA, less estimated costs to sell. The impairment will be updated, if necessary, based on the final execution of the purchase sale agreement and any changes in ~~the~~ estimated fair value as additional information related to the potential transaction becomes available.

In 2013, a FERC Administrative Law Judge issued an initial decision ~~holding~~ that Duke Energy Ohio is responsible for certain MVP costs, a type of MTEP cost, approved by MISO prior to the date of Duke Energy Ohio’s withdrawal. The initial decision will be reviewed by FERC. If FERC upholds the initial decision, Duke Energy Ohio intends to file an appeal in federal court. If Duke Energy Ohio ~~ultimately~~ is ~~found to be~~deemed responsible for these costs, and if a portion of these costs ~~may~~are not be eligible for recovery, ~~resulting in~~there may be an adverse impact to its financial position, results of operations and cash flows. See Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters,” for additional information.

~~111~~115

PART I

DUKE ENERGY INDIANA

The results of operations and variance discussion is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

Results of Operations


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014		2013		Variance		2014		2013		Variance
Operating Revenues	$	1,593	$	1,424	$	169	$	2,383	$	2,179	$	204
Operating Expenses	1,200		1,075		125		1,808		1,627		181
Operating Income	393		349		44		575		552		23
Other Income and Expenses, net	11		10		1		16		14		2
Interest Expense	87		84		3		127		127		—
Income Before Income Taxes	317		275		42		464		439		25
Income Tax Expense	117		103		14		163		163		—
Net Income	$	200	$	172	$	28	$	301	$	276	$	25



Increase over prior year	2014
Residential sales	~~7.7~~3.3	%
General service sales	~~1.8~~0.6	%
Industrial sales	2.5	%
Wholesale power sales	~~18.4~~3.4	%
Total sales	~~5.4~~1.4	%
Average number of customers	0.6	%

~~Six~~Nine Months Ended ~~June~~September 30, 2014 as Compared to ~~June~~September 30, 2013

Operating Revenues. The variance was driven primarily by:

A ~~$77 million net increase in rate riders primarily due to updates to the integrated gasification combined cycle (IGCC) rider;~~

~~A $63~~$96 million increase in fuel revenues (including emission allowances) due to an increase in fuel rates as a result of higher fuel and purchased power costs;

An ~~$11~~$89 million net increase in rate riders primarily due to updates to the integrated gasification combined cycle (IGCC) rider; and

A $9 million increase in weather-normal sales volumes to retail customers (net of fuel revenue) reflecting increased ~~demand; and~~

~~An $8 million increase in electric sales (net of fuel revenue) to retail customers due to favorable weather conditions.~~demand.

Operating Expenses. The variance was driven primarily by:

A ~~$57~~$93 million increase in fuel costs primarily driven by higher fuel and purchased power costs;

~~A $50~~An $82 million increase in depreciation and amortization primarily as a result of the Edwardsport IGCC plant being placed into service in the second quarter of ~~2013; and~~

A $12 million increase in operation and maintenance primarily due to higher operation and maintenance costs, and increased retail customer services costs, partially offset by lower amortization of certain previously deferred operations and maintenance expenses.2013.

Income Tax Expense.~~The variance was primarily due to an increase in pretax income.~~ The effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013 was ~~36.8~~35.2 percent and ~~37.5~~37.2 percent, respectively. The decrease in the effective tax rate was primarily due to a reduction in the Indiana statutory corporate state income tax rate and a prior period audit settlement.

Matters Impacting Future Results

Duke Energy Indiana is evaluating converting Wabash River Unit 6 to a natural gas-fired unit or retiring the unit earlier than its current estimated useful life. If Duke Energy Indiana elects early retirement of the unit, recovery of remaining book values and associated carrying costs totaling approximately $40 million could be subject to future regulatory approvals and therefore cannot be assured.

~~112~~116

PART I

LIQUIDITY AND CAPITAL RESOURCES

Sources and Uses of Cash

Duke Energy relies primarily upon cash flows from operations, debt issuances and its existing cash and cash equivalents to fund its domestic liquidity and capital requirements. Duke Energy’s capital requirements arise primarily from capital and investment expenditures, repaying long-term debt and paying dividends to shareholders. See Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013 for a summary of primary sources and uses of cash for 2014 – 2016 and a more detailed discussion of each.

The Subsidiary Registrants generally maintain minimal cash balances and use short-term borrowings to meet their working capital needs and other cash requirements. The Subsidiary Registrants, excluding Progress Energy, support their short-term borrowing needs through participation with Duke Energy and certain of its other subsidiaries in a money pool arrangement. The companies with short-term funds may provide short-term loans to affiliates participating under this arrangement.

Duke Energy and the Subsidiary Registrants, excluding Progress Energy, may also use short-term debt, including commercial paper and the money pool, as a bridge to long-term debt financings. The levels of borrowing may vary significantly over the course of the year due to the timing of long-term debt financings and the impact of fluctuations in cash flows from operations. Duke Energy’s current liabilities ~~frequently~~may at times exceed current assets resulting from the use of short-term debt as a funding source to meet scheduled maturities of long-term debt, as well as cash needs, which can fluctuate due to the seasonality of its business.

Credit Facility and Registration Statements

Master Credit Facility Summary

Duke Energy has a ~~master credit facility~~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~~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~~Master Credit Facility has been reduced to backstop issuances of commercial paper, certain letters of credit and variable-rate demand tax-exempt bonds that may be put to the Duke Energy Registrants at the option of the holder. The table below includes the current borrowing sublimits and available capacity under the ~~master credit facility.~~Master Credit Facility.


	June 30, 2014																					September 30, 2014
(in millions)	Duke Energy			Duke Energy (Parent)			Duke Energy Carolinas			Duke Energy Progress			Duke Energy Florida			Duke Energy Ohio			Duke Energy Indiana			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		$	6,000		$	2,250		$	1,000		$	750		$	650		$	650		$	700
Reduction to backstop issuances
Notes payable and commercial paper^(b)	(1,409		)	(873		)	(300		)	(75		)	—			(11		)	(150		)
Commercial paper^(b)																						(1,278		)	(784		)	(300		)	(27		)	—			(4		)	(163		)
Outstanding letters of credit	(64		)	(57		)	(4		)	(2		)	(1		)	—			—			(64		)	(56		)	(4		)	(2		)	(1		)	—			(1		)
Tax-exempt bonds	(156		)	—			(75		)	—			—			—			(81		)	(116		)	—			(35		)	—			—			—			(81		)
Available capacity	$	4,371		$	1,320		$	621		$	673		$	649		$	639		$	469		$	4,542		$	1,410		$	661		$	721		$	649		$	646		$	455


(a)	Represents the sublimit of each ~~borrower at June 30, 2014.~~borrower.


(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 within ~~Long-term~~Long-Term Debt Payable to Affiliated Companies in Duke Energy Carolinas' and Duke Energy Indiana’s Condensed Consolidated Balance Sheets.

PremierNotes

Duke Energy has an effective Form S-3 with the ~~SEC~~Securities and Exchange Commission (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 ~~June~~September 30, 2014 and December 31, 2013 was ~~$909~~$960 million and $836 million, respectively. The notes are short-term debt obligations of Duke Energy and are ~~reflected as~~classified within Notes payable and commercial paper on Duke Energy’s Condensed Consolidated Balance Sheets.

Shelf Registration

In September 2013, Duke Energy filed a 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.

~~113~~117

PART I

DEBT MATURITIES


(in millions)	Maturity Date	Interest Rate		June 30, 2014		Maturity Date	Interest Rate		September 30, 2014
Unsecured Debt
Duke Energy (Parent)	September 2014	3.950	%	$	500	April 2015	3.350	%	$	450
Duke Energy (Parent)	April 2015	3.350	%	450
Duke Energy	July 2014	15.370	%	196
First Mortgage Bonds
Duke Energy Ohio	March 2015	0.370	%	150		March 2015	0.373	%	150
Duke Energy Progress	April 2015	5.150	%	300		April 2015	5.150	%	300
Other				291					256
Current maturities of long-term debt				$	1,887				$	1,156

CASH FLOWS FROM OPERATING ACTIVITIES

The relatively stable operating cash flows of Regulated Utilities compose a substantial portion of Duke Energy’s cash flows from operations. Regulated Utilities’ cash flows from operations are primarily driven by sales of electricity and natural gas and costs of operations. Weather conditions, commodity price fluctuations and unanticipated expenses, including unplanned plant outages and storms, can affect the timing and level of cash flows from operations.

Duke Energy provides the liquidity support for Commercial Power’s coal-fired and gas-fired assets that are dispatched into the PJM wholesale market. Commercial Power has economically hedged a portion of its forecasted generation through 2018 with various counterparties, and a substantial portion of these contracts require daily posting of margin, which can be significant. On August 21, 2014, Duke Energy ~~believes it has sufficient liquidity resources through~~Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a purchase and sale agreement with a subsidiary of Dynegy whereby Dynegy will acquire the ~~commercial paper markets,~~Disposal Group, including Commercial Power’s coal-fired and ~~ultimately~~gas-fired assets. In the ~~master credit facility,~~third quarter of 2014, the results of operations of the Disposal Group were classified as discontinued operations for current and prior periods in the accompanying Condensed Consolidated Statements of Operations and Comprehensive Income. The transaction is expected to ~~support~~close in the fourth quarter of 2014 or the first quarter of 2015. See Note 2 to the Condensed Consolidated Financial Statements, "Acquisitions and Dispositions," for further discussion on the Midwest generation exit. After the close of the sale, Duke Energy will no longer have margin requirements associated with these ~~operations.~~ hedging activities.

Cash flows from operations are subject to a number of other factors, including but not limited to regulatory constraints, economic trends and market volatility (see “Item 1A. Risk Factors,” in the Duke Energy Registrants’ Annual Report on Form 10-K for the year ended December 31, 2013 for additional information).

At ~~June~~September 30, 2014, Duke Energy had cash and cash equivalents and short-term investments of $2$1.9 billion, of which ~~$1.7~~$1.6 billion is held by entities domiciled in foreign jurisdictions and is forecasted to be used to fund the operations of and investments in International Energy. Undistributed earnings associated with foreign operations are considered indefinitely reinvested. As a result, no U.S. tax is recorded on such earnings. This assertion is based on management’s determination the cash held in foreign jurisdictions is not needed to fund Duke Energy’s U.S. operations and that it either has invested or has intentions to reinvest such earnings. While management currently intends to indefinitely reinvest all unremitted foreign earnings, should circumstances change, Duke Energy may need to record additional income tax expense in the period in which such determination changes. The cumulative undistributed earnings as of ~~June~~September 30, 2014, on which Duke Energy has not provided deferred U.S. income taxes and foreign withholding taxes, is approximately $2.6 billion. The amount of unrecognized deferred tax liability related to these undistributed earnings is estimated at ~~between $360 million and $435~~approximately $300 million.

Duke Energy is conducting a strategic review of its international business. The review is considering a wide range of options and opportunities for growth of the business, including strategies for utilization of off-shore cash. Duke Energy expects to complete the strategic review in late 2014 or early 2015.

Restrictive Debt Covenants

The Duke Energy Registrants’ debt and credit agreements contain various financial and other covenants. The ~~master credit facility~~Master Credit Facility contains a covenant requiring the debt-to-total capitalization ratio to 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 ~~June~~September 30, 2014, each of the Duke Energy Registrants was in compliance with all covenants related to their significant debt agreements. In addition, some credit agreements may allow for acceleration of payments or termination of the agreements due to nonpayment, or the 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.

Credit Ratings

Credit ratings are intended to provide credit lenders a framework for comparing the credit quality of securities and are not a recommendation to buy, sell or hold. The Duke Energy Registrants’ credit ratings are dependent on the rating agencies’ assessments of their ability to meet their debt principal and interest obligations when they come due. If, as a result of market conditions or other factors, the Duke Energy Registrants are unable to maintain current balance sheet strength, or if earnings and cash flow outlook materially deteriorates, credit ratings could be negatively impacted.

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The Duke Energy Registrants each hold credit ratings by Fitch Ratings, Inc. (Fitch), Moody’s Investors Service, Inc. (Moody’s) and Standard & Poor’s Rating Services (S&P). The Duke Energy Registrants' credit ratings at Fitch, Moody’s and S&P have not changed since February 13, 2014, and their outlooks remain stable, excluding Fitch's outlook for Duke Energy ~~Carolinas.~~Carolinas and S&P's outlook for the Duke Energy Registrants. On June 17, 2014, Fitch revised Duke Energy Carolinas' outlook to positive from stable. On November 5, 2014, S&P revised the Duke Energy ~~Carolinas' rating~~Registrants outlook to positive from ~~Fitch was revised from stable to positive. The credit ratings for Duke Energy Carolinas are stable at Moody's and S&P.~~stable.

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~~PART I~~

Cash Flow Information

The following table summarizes Duke Energy’s cash flows.


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
Cash flows provided by (used in):
Operating activities	$	2,619		$	2,843		$	5,167		$	4,990
Investing activities	(2,367		)	(2,562		)	(3,734		)	(3,566		)
Financing activities	255			(134		)	(1,003		)	(682		)
Net increase in cash and cash equivalents	507			147			430			742
Cash and cash equivalents at beginning of period	1,501			1,424			1,501			1,424
Cash and cash equivalents at end of period	$	2,008		$	1,571		$	1,931		$	2,166

OPERATING CASH FLOWS

The following table summarizes key components of Duke Energy’s operating cash flows.


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
Net income	$	520		$	976		$	1,789		$	1,984
Non-cash adjustments to net income	3,012			2,367			3,909			3,856
Contributions to qualified pension plans							—			(27		)
Working capital	(913		)	(500		)	(531		)	(823		)
Net cash provided by operating activities	$	2,619		$	2,843		$	5,167		$	4,990

The variance was driven primarily ~~by:~~due to:

~~A $413 million decrease in working capital mainly due to~~Increased retail pricing and rate riders and favorable weather; partially offset by the under collection of fuel and purchased power ~~costs due to increased consumption and current year incentive payments, net of accruals.~~costs.

~~Partially offset by:~~

~~A $189 million increase in net income after non-cash adjustments, mainly due to increased retail pricing and rate riders, favorable weather and weather-normal volumes.~~

INVESTING CASH FLOWS

The following table summarizes key components of Duke Energy’s investing cash flows.


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
Capital, investment and acquisition expenditures	$	(2,454	)	$	(2,764	)	$	(3,836	)	$	(3,907	)
Available for sale securities, net	20			(52		)	21			96
Proceeds from sales of other assets	119			38			172			59
Other investing items	(52		)	216			(91		)	186
Net cash used in investing activities	$	(2,367	)	$	(2,562	)	$	(3,734	)	$	(3,566	)

The variance was primarily due to:

~~A $310 million decrease in capital, investment and acquisition expenditures primarily due to lower spending for expansion and maintenance projects at Regulated Utilities and~~

~~An $81 million increase in proceeds due to the sale of Las Flores at International Energy.~~

~~Partially offset by:~~

A $192 million return of collateral related to the Chilean hydro acquisition in ~~2013.~~2013 and

A $75 million decrease in net proceeds from sales and maturities of available for sale securities, net of purchases.

Partially offset by:

A $113 million increase in proceeds, mainly due to the sale of Las Flores at International Energy.

~~115~~119

PART I

FINANCING CASH FLOWS

The following table summarizes key components of Duke Energy’s financing cash flows.


	Six Months Ended June 30,						Nine Months Ended September 30,
(in millions)	2014			2013			2014			2013
Issuance of common stock related to employee benefit plans	$	23		$	7		$	24		$	8
Issuance of long-term debt, net	331			294
(Redemption) Issuance of long-term debt, net							(286		)	487
Notes payable and commercial paper	1,024			763			941			537
Dividends paid	(1,107		)	(1,085		)	(1,670		)	(1,636		)
Other financing items	(16		)	(113		)	(12		)	(78		)
Net cash provided by (used in) financing activities	$	255		$	(134	)
Net cash used in financing activities							$	(1,003	)	$	(682	)

The variance was due primarily to:

A ~~$261~~$773 million decrease in net issuances of long-term debt, primarily due to the timing of issuances and redemptions across years.

Partially offset by:

A $404 million increase in proceeds from net issuances of notes payable and commercial paper, primarily to fund ~~the~~ short-term working capital ~~needs;~~needs and

A $96 million prior year payment for the redemption of preferred stock of subsidiaries.

Summary of Significant Debt Issuances

The following table summarizes significant debt issuances (in millions).


				Six Months Ended June 30, 2014											Nine Months Ended September 30, 2014
Issuance Date	Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy		Maturity Date	Interest Rate		Duke Energy (Parent)		Duke Energy Progress		Duke Energy Florida		Duke Energy
Unsecured Debt
April 2014^(a)	April 2024	3.750	%	$	600	$	—	$	—	$	600	April 2024	3.750	%	$	600	$	—	$	—	$	600
April 2014^(a)	April 2017	0.610	%	400		—		—		400		April 2017	0.612	%	400		—		—		400
June 2014^(b)	May 2019	10.700	%	—		—		—		108		May 2019	11.870	%	—		—		—		108
June 2014^(b)	May 2021	13.900	%	—		—		—		110		May 2021	13.680	%	—		—		—		110
Secured Debt
March 2014^(c)	March 2017	0.854	%	—		—		225		225		March 2017	0.854	%	—		—		225		225
July 2014^(d)												July 2036	5.340	%	—		—		—		129
First Mortgage Bonds
March 2014^(d)	March 2044	4.375	%	—		400		—		400
March 2014^(d)(e)	March 2017	0.430	%	—		250		—		250		March 2044	4.375	%	—		400		—		400
March 2014^(e)												March 2017	0.433	%	—		250		—		250
Total issuances				$	1,000	$	650	$	225	$	2,093				$	1,000	$	650	$	225	$	2,222


(a)	Proceeds ~~will be~~were used to redeem $402 million of tax-exempt bonds at Duke Energy Ohio, the repayment of outstanding commercial paper and for general corporate purposes. See Note 89 to the Condensed Consolidated Financial Statements, "Related Party Transactions," for additional information related to the redemption of Duke Energy Ohio's tax-exempt bonds.


(b)	Proceeds ~~will be~~were used to repay $196 million of ~~current maturities~~debt at International Energy and for general corporate purposes.


(c)	Relates to the securitization of accounts receivable at a subsidiary of Duke Energy Florida. Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes. See Note 1213 to the Condensed Consolidated Financial Statements, "Variable Interest Entities," for further details.


(d)	Proceeds were used to fund a portion of Duke Energy's prior investment in the existing Wind Star renewables portfolio.


(e)	Proceeds were used to repay short-term borrowings under the intercompany money pool borrowing arrangement and for general corporate purposes.

OTHER MATTERS

Midwest Generation Exit

Merchant power plants have in the recent past delivered volatile returns in the competitive energy markets in the Midwest. In Ohio, the Public Utilities Commission of Ohio (PUCO) had granted revenue support from regulated retail markets to help stabilize returns during the transition to competitive markets. However, in early 2014 a request for continued revenue support was denied by the PUCO. This decision made it clear the energy markets in Ohio were to be fully unregulated. Although the undiscounted cash flows recover the carrying value of the Midwest Generation assets, the recovery period is over a long period of time, with risks inherent in operating these assets in competitive energy markets and in an ever changing landscape of environmental regulations related to fossil fuel based generation sources. Management concluded in early 2014 that the projected risk and earnings profile of these assets was no longer consistent with Duke Energy’s strategy and initiated a plan to sell these assets and realize the fair value over a shorter period while reducing the risk and volatility associated with these assets.

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On August 21, 2014, Duke Energy Commercial Enterprises, Inc., an indirect wholly owned subsidiary of Duke Energy Corporation, and Duke Energy SAM, LLC, a wholly owned subsidiary of Duke Energy Ohio, entered into a PSA with a subsidiary of Dynegy whereby Dynegy will acquire Duke Energy Ohio’s Disposal Group for approximately $2.8 billion in cash subject to adjustments at closing for changes in working capital and capital expenditures. The completion of the transaction is conditioned on expiration or termination of any applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, approval by FERC, and the release of certain credit support obligations. Closing is expected to be completed in the fourth quarter of 2014 or the first quarter of 2015.

North Carolina Ash Basins

incident. See Note 5 to the Condensed Consolidated Financial Statements, ~~“Commitments~~"Commitments and Contingencies,”" for further discussion of Duke Energy’s response to the release.

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~~PART I~~

~~Midwest Generation Exit~~

On February 17, 2014, Duke Energy announced it had initiated a process to exit its nonregulated Midwest generation business. Duke Energy expects to dispose of the nonregulated Midwest generation business by the end of the first quarter of 2015.

Duke Energy recorded a pretax impairment on these assets of approximately $1.4 billion for the six months ended June 30, 2014, which represents the excess of the carrying value over the estimated fair value of the business, less estimated costs to sell. The fair value of the disposal group was based on the income approach, which estimates fair value using discounted cash flows, and indicative bids received to date. The impairment will be updated, if necessary, based on changes in estimated fair value as additional information related to the potential transaction becomes available.

Duke Energy continues to believe the carrying value of the nonregulated Midwest Generation assets are recoverable under a scenario where it would continue to own and operate the assets. However, merchant power plants have in the recent past delivered volatile returns in the competitive energy markets in the Midwest. In Ohio, the PUCO had granted revenue support from regulated retail markets to help stabilize returns during the transition to competitive markets. However, in early 2014 a request for continued revenue support was denied by the PUCO. This decision made it clear the energy markets in Ohio were to be fully unregulated. Although the undiscounted cash flows recover the carrying value of these assets, the recovery period is over a long period of time, with risks inherent in operating these assets in competitive energy markets and in an ever changing landscape of environmental regulations related to fossil fuel based generation sources. Therefore, management initiated a plan to sell these assets to realize the fair value over a shorter period while reducing the risk and volatility associated with these assets. Ultimately, management concluded in early 2014 that the projected risk and earnings profile of these assets was no longer consistent with Duke Energy’s strategy.

Environmental Regulations

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~~and result in new obligations onof the Duke Energy Registrants.

The following sections outline various proposed and recently enacted regulations that may impact the Duke Energy Registrants.

~~Clean Water~~Coal Ash Management Act ~~316(b)~~of 2014

On September 20, 2014, the North Carolina Coal Ash Management Act of 2014 (Coal Ash Act) became law. The ~~EPA signed~~bill (i) establishes a Coal Ash Management Commission to oversee handling of coal ash within the ~~final 316(b) cooling~~state; (ii) prohibits construction of new and expansion of existing ash impoundments and use of existing impoundments at retired facilities, effective October 1, 2014; (iii) requires closure of ash impoundments at Duke Energy Progress' Asheville and Sutton stations and Duke Energy Carolinas' Riverbend and Dan River stations no later than August 1, 2019; (iv) requires conversion to dry fly ash handling at active plants not retired by December 31, 2018; (v) requires conversion to dry bottom ash handling at active plants by December 31, 2019, or retirement of active plants; (vi) requires all remaining ash impoundments in North Carolina to be approved as high-risk, intermediate-risk, or low-risk no later than December 31, 2015 by The North Carolina Department of Environment and Natural Resources (DENR) with the method of closure and timing to be based upon the assigned risk, with closure no later than December 31, 2029; (vii) establishes requirements to deal with groundwater and surface water ~~intake structure rule on May 19,~~impacts from impoundments and (viii) enhances the level of regulation for structural fills utilizing coal ash. A variance procedure for compliance deadlines and modification of requirements regarding structural fills and compliance boundaries is also outlined. Provisions of the bill prohibit cost recovery for unlawful discharge of ash basin waters occurring after January 1, 2014. The ~~rule will be effective 60 days after publication in~~Coal Ash Act includes a moratorium for any NCUC ordered rate changes to effectuate the ~~Federal Register~~legislation, which ends January 15, 2015. The Coal Ash Act leaves the decision on cost recovery determinations related to closure of coal combustion residuals surface impoundments (ash basins or impoundments) to the normal ratemaking processes before utility regulatory commissions. In September 2014, Duke Energy Carolinas executed a consent agreement with the South Carolina Department of Health and ~~will be applicable~~Environmental Control (SCDHEC) requiring the retirement of an inactive ash basin at the W.S. Lee Steam Station. For further information, refer to ~~27 to 32~~Note 5 of the ~~steam electric generating facilities~~Condensed Consolidated Financial Statements, “Commitments and Contingencies.”

The table below provides the ~~Duke Energy Registrants own and operate depending on unit retirement dates and~~estimated costs to comply with the ~~date~~requirements of the ~~divestiture~~Coal Ash Act to convert to dry fly ash and dry bottom ash handling at active plants. Ash basin closure costs recorded at September 30, 2014 are excluded from this table. For further information, refer to Note 7 of ~~Duke Energy Ohio's nonregulated Midwest generation assets. The rule allows several options for demonstrating compliance and provides flexibility to~~ the state environmental permitting agencies to make determinations on controls, if any, that will be required for cooling water intake structures. Any intake structure modifications and/or retrofits that are required would need to be in place in the 2019 to 2022 timeframe. Given the number of compliance options allowed, and the fact that the final determination of controls required will be made by the state permitting agencies, the Duke Energy Registrants are unable to predict the cost of compliance at this time.Condensed Consolidated Financial Statements, "Asset Retirement Obligations."



(in millions)	Range
Duke Energy	$	425	—	$	650
Duke Energy Carolinas	250		—	375
Progress Energy	175		—	275
Duke Energy Progress	175		—	275

Cross-State Air Pollution Rule

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 NO_x budgets that were to take effect on January 1, 2012.

121

PART I

On August 21, 2012, the ~~D.C.~~U.S. Court of Appeals for the District of Columbia (D.C. Circuit ~~Court~~Court) vacated the CSAPR. The court also directed the ~~EPA~~Environmental Protection Agency (EPA) to continue administering the Clean Air Interstate Rule (CAIR). The CAIR requires additional reductions in SOsulfur dioxide (SO₂) and NOnitrogen oxide (NO_x) emissions beginning in 2015. On April 29, 2014, the U.S. Supreme Court (Supreme Court) reversed the D.C. Circuit Court’s decision, finding that with CSAPR the EPA reasonably interpreted the good neighbor provision of the Clean Air Act. The case ~~has been~~was remanded to the D.C. Circuit Court for further proceedings consistent with the Supreme Court’s opinion. ~~As part of those proceedings, the EPA has requested~~On October 23, 2014, the D.C. Circuit Court ~~lift~~lifted the ~~CSAPR~~ stay and ~~direct~~directed Phase 1 of the rule to take effect on January 1, 2015. ~~The Duke Energy Registrants cannot predict the outcome of the proceedings.~~

~~If or when~~When the CSAPR takes effect, the stringency of the CSAPR requirements will vary among the Duke Energy Registrants. Where the CSAPR requirements are constraining, actions to meet the requirements could include purchasing emission allowances, power purchases, curtailing generation and utilizing low sulfur fuel. The CSAPR is not expected to result in Duke Energy Registrants adding new emission controls.

Coal Combustion Residuals

On June 21, 2010, the EPA proposed a regulation under the Resource Conservation and Recovery Act, related to coal combustion residuals (CCR) associated with the generation of electricity from coal. 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 revised court order to finalize the rule by September 30, 2015. 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. Requirements to comply with the final rule may begin as early as late 2018 for some facilities. The Duke Energy Registrants are unable to predict the outcome of the rulemaking, but the impact could be significant.

~~117~~

~~PART I~~

Carbon Dioxide New Source Performance Standards

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 appeared in the Federal Register. Based on the proposal, 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.

CO₂ Existing Source Performance Standards and Standards for Reconstructed and Modified Units

The EPA proposed CO₂ emission guidelines for existing fossil fuel-fired electric generating units were published in the Federal Register on June 18, 2014. ~~After a 120-day public~~On the same date, the EPA proposed standards for reconstructed and modified units. The comment period for the existing source proposal will end December 1, 2014. The comment period for the reconstructed and modified units proposal ended October 16, 2014. The EPA is expected to finalize ~~the guidelines~~both proposals by June 1, 2015. Once emission guidelines for existing sources are finalized, states will be required to develop regulations that will apply to covered sources, based on the emission performance standards established by the EPA in its guidelines. Based on the EPA proposal, states are to develop and submit their regulations to the EPA for approval between June 30, 2016 and June 30, 2018. The EPA has proposed a ~~phasing in~~phasing-in of CO₂ emission reductions ~~over~~during the period 2020 to 2030. The Duke Energy Registrants are unable to predict the outcome of this rulemaking, but the impact could be significant.

Clean Water Act 316(b)

The EPA signed the final 316(b) cooling water intake structure rule on May 19, 2014. The rule became effective October 14, 2014, and will be applicable to 27 of the steam electric generating facilities the Duke Energy Registrants own and operate depending on unit retirement dates. The rule allows several options for demonstrating compliance and provides flexibility to the state environmental permitting agencies to make determinations on controls, if any, that will be required for cooling water intake structures. Any required intake structure modifications and/or retrofits are expected to be installed in the 2019 to 2022 timeframe. Petitions challenging the rule have been filed by Environment American and Environment Massachusetts, the River Keeper, Inc. et al., Sierra Club and the Utility Water Activities Group and Entergy Corporation.

The table below provides estimated costs to comply, assuming no station is required to retrofit to closed-cycle cooling. These numbers represent a rough order of magnitude given the number of compliance options allowed, and the fact that the final determination of controls required will be made by the state permitting agencies.



(in millions)	Range
Duke Energy	$	390	—	$	480
Duke Energy Carolinas	165		—	190
Progress Energy	210		—	250
Duke Energy Progress	60		—	75
Duke Energy Florida^(a)	150		—	175
Duke Energy Indiana	15		—	40

(a) Assumes Crystal River Units 1 and 2 and Suwannee are retired prior to the timeframe for required modifications.

122

PART I

Mercury and Air Toxics Standards

The final Mercury and Air Toxics Standards (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~~installation of new air emission control equipment, ~~developing~~development of monitoring processes, fuel switching, and ~~accelerating~~acceleration of retirement offor some coal-fired ~~electric-generating~~electric-generation units. For additional information, refer to Note 4 to the Condensed Consolidated Financial Statements, "Regulatory Matters," regarding potential plant retirements.

In April 2014, several petitions for review of the final rule were denied by the D.C. Circuit Court. Several petitioners in the case have requested the Supreme Court review the D.C. Circuit Court's decision. The Duke Energy Registrants cannot predict the outcome of the litigation and are planning for the rule to be implemented as promulgated. Refer to the table below for a summary of estimated costs to comply with regulations.

The table below includes estimated undiscounted costs for new control equipment necessary to comply with the MATS ~~regulations.~~rule,



(in millions)	Range
Duke Energy	$	850	—	$	975
Duke Energy Carolinas	275		—	310
Progress Energy	80		—	95
Duke Energy Progress	20		—	25
Duke Energy Florida	60		—	70
Duke Energy Ohio	45		—	70
Duke Energy Indiana	450		—	500

Estimated Cost and Impacts of ~~EPA~~ Rulemakings

The ultimate compliance requirements for the above environmental regulations 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 and certain ash basin management costs to comply with these EPA regulations could total $5 billion to $6 billion, excluding AFUDC, over the next 10 years. A portion of the costs in this range, including actions outlined in a March 12, 2014 letter to the governor of the state of North Carolina, is included in the baseline assumptions included in the Ash Basins disclosure in Note 5. This estimate assumes coal ash will retain a non-hazardous designation and primarily assumes cap in place closure for ash basins. The cost estimate would be significantly higher if coal ash is deemed a hazardous material and if coal ash is required to be excavated and relocated to lined landfills.

~~The table below includes estimated costs for new control equipment necessary to comply with the MATS rule, which is the only rule that has become effective.~~

(in millions) Range
Duke Energy $ 525
— 625
Duke Energy Carolinas 40
— 50
Progress Energy 25
— 40
Duke Energy Progress 10
— 15
Duke Energy Florida 15
— 25
Duke Energy Ohio 35
— 50
Duke Energy Indiana 425
— 485

The Duke Energy Registrants also expect to incur increased fuel, purchased power, operation and maintenance, and other expenses, ~~and~~in addition to 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 to the Condensed Consolidated Financial Statements, “Regulatory Matters," for further information regarding potential plant retirements and regulatory filings related to the Duke Energy Registrants.

Global Climate Change

For other information on global climate change and the potential impacts on Duke Energy, see “Other Issues” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013.

Nuclear Matters

For other information on nuclear matters and the potential impacts on Duke Energy, see “Other Issues” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013.

~~118~~

~~PART I~~

New Accounting Standards

See Note 1 to the Condensed Consolidated Financial Statements, “Organization and Basis of Presentation,” for a discussion of the impact of new accounting standards.

Off-Balance Sheet Arrangements

During the three and ~~six~~nine months ended ~~June~~September 30, 2014, there were no material changes to Duke Energy’s off-balance sheet arrangements. For information on Duke Energy’s off-balance sheet arrangements, see “Off-Balance Sheet Arrangements” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013.

Contractual Obligations

Duke Energy enters into contracts that require payment of cash at certain specified periods, based on certain specified minimum quantities and prices. During the three and ~~six~~nine months ended ~~June~~September 30, 2014, there were no material changes in Duke Energy’s contractual obligations. For an in-depth discussion of Duke Energy’s contractual obligations, see “Contractual Obligations” and “Quantitative and Qualitative Disclosures about Market Risk” in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013.

Subsequent Events

See Note 1718 to the Condensed Consolidated Financial Statements, “Subsequent Events,” for a discussion of subsequent events.

123

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

During the three and ~~six~~nine months ended ~~June~~September 30, 2014, there were no material changes to Duke Energy’s disclosures about market risk. For an in-depth discussion of Duke Energy’s market risks, see “Management’s Discussion and Analysis of Quantitative and Qualitative Disclosures about Market Risk” in Duke Energy’s Annual Report on Form 10-K for the year ended December 31, 2013.

ITEM 4. CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures that are designed to ensure that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Securities Exchange Act of 1934 (Exchange Act) is recorded, processed, summarized, and reported within the time periods specified by the ~~Securities and Exchange Commission’s (SEC)~~SEC rules and forms.

Disclosure controls and procedures include, without limitation, controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Duke Energy Registrants in the reports they file or submit under the Exchange Act is accumulated and communicated to management, including the Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated the effectiveness of their disclosure controls and procedures (as such term is defined in Rule 13a-15(e) and 15d-15(e) under the Exchange Act) as of ~~June~~September 30, 2014, and, based upon this evaluation, the Chief Executive Officer and Chief Financial Officer have concluded that these controls and procedures are effective in providing reasonable assurance of compliance.

Changes in Internal Control over Financial Reporting

Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, the Duke Energy Registrants have evaluated changes in internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during the fiscal quarter ended ~~June~~September 30, 2014 and have concluded no change has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.

~~119~~124

PART II. OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

For information regarding legal proceedings that became reportable events or in which there were material developments in the ~~second~~third quarter of 2014, see Note 4 to the Condensed Consolidated Financial Statements, “Regulatory Matters” and Note 5 to the Condensed Consolidated Financial Statements, “Commitments and Contingencies — Litigation” and “Commitments and Contingencies — Environmental.”

ITEM 1A. RISK FACTORS

In addition to the other information set forth in this report, careful consideration should be given to the factors discussed in Part I, “Item 1A. Risk Factors” in the Duke Energy Registrants’ Annual Report on Form 10-K for the year ended December 31, 2013, which could materially affect the Duke Energy Registrants’ financial condition or future results.

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

ISSUER PURCHASES OF EQUITY SECURITIES

There were no issuer purchases of equity securities during the ~~second~~third quarter of 2014.

~~120~~125

PART II

ITEM 6. EXHIBITS

Exhibits filed herein are ~~designed~~designated by an asterisk (*). All exhibits not so designated are incorporated by reference to a prior filing, as indicated. Items constituting management contracts or compensatory plans or arrangements are designated by a double asterisk (**). The Company agrees to furnish upon request to the Commission a copy of any omitted schedules or exhibits upon request on all items designated by a triple asterisk (***).

Exhibit

Number

Duke Energy

Carolinas

Progress Energy

Duke Energy Progress

Duke Energy Florida

Duke Energy Ohio

Duke Energy

Indiana

~~3.1~~10.1

~~Amended and Restated Certificate of Incorporation of~~

Agreement between Duke Energy ~~Corporation, effective May 20,~~SAM, LLC, Duke Energy Ohio, Inc., Duke Energy Commercial Enterprise, Inc. and Dynegy Resource I, LLC, dated August 21, 2014 (incorporated by reference to Exhibit ~~3.1~~99.1 to ~~Duke Energy Corporation’s~~registrant’s Current Report on Form 8-K filed on ~~May 20,~~August 22, 2014, File ~~No. 1-32853)~~Nos. 1-32853 and 1-1232).

~~4.1~~10.2

~~Eleventh Supplemental Indenture,~~Asset Purchase Agreement between Duke Energy Progress, Inc. and North Carolina Eastern Municipal Power Agency dated ~~as of April 4,~~September 5, 2014 ~~between the Company and The Bank of New York Mellon Trust Company, N.A.~~

~~(incorporated~~(incorporated by reference to ~~Exhibit 4.1 of Duke Energy Corporation's~~Item 1.01 to registrant’s Current Report on Form 8-K filed on ~~April 4,~~September 8, 2014, File ~~No. 1-32853)~~Nos. 1-32853 and 1-3382).

*12.1

Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY CORPORATION

*1212.2

Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY CAROLINAS

*12.3

Computation of Ratio of Earnings to Fixed Charges - PROGRESS ENERGY

*12.4

Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY PROGRESS

*12.5

Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY FLORIDA

*12.6

Computation of Ratio of Earnings to Fixed Charges - DUKE ENERGY INDIANA

*31.1.1

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.2

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.3

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.4

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.5

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.6

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.1.7

Certification of the Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.1

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.2

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.3

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.4

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

126

PART II

*31.2.5

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.6

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*31.2.7

Certification of the Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

*32.1.1

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.2

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

~~121~~

~~PART II~~

*32.1.3

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.4

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.5

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.6

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.1.7

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.1

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.2

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.3

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.4

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.5

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.6

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*32.2.7

Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

*101.INS

XBRL Instance Document

*101.SCH

XBRL Taxonomy Extension Schema Document

*101.CAL

XBRL Taxonomy Calculation Linkbase Document

*101.LAB

XBRL Taxonomy Label Linkbase Document

*101.PRE

XBRL Taxonomy Presentation Linkbase Document

*101.DEF

XBRL Taxonomy Definition Linkbase Document

The total amount of securities of the registrant or its subsidiaries authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10 percent of the total assets of the registrant and its subsidiaries on a consolidated basis. The registrant agrees, upon request of the ~~Securities and Exchange Commission (SEC),~~SEC, to furnish copies of any or all of such instruments to it.

~~122~~127

PART II

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.



		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.

Date:	~~August~~November 7, 2014	/S/ STEVEN K. YOUNG
		Steven K. Young Executive Vice President and Chief Financial Officer

Date:	~~August~~November 7, 2014	/S/ BRIAN D. SAVOY
		Brian D. Savoy Senior Vice President, ~~Controller and~~ Chief Accounting Officer and Controller

~~123~~128



(in billions)	Range
Baseline assumptions^(a)	$	2.0	-	$	2.5
Estimated additional costs related to full excavation^(b)	4.0		-	5.5
Estimated additional costs related to all-dry systems^(c)	1.0		-	2.0
Total range of costs^(d)	$	2.0	-	$	10.0



(In millions, except per-share amounts)	Income		Average Shares	EPS
Three Months Ended June 30, 2014
Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	611	707	$	0.86
Three Months Ended June 30, 2013
Income from continuing operations attributable to Duke Energy common shareholders, as adjusted for participating securities — basic and diluted	$	340	706	$	0.48